[Federal Register Volume 81, Number 66 (Wednesday, April 6, 2016)]
[Rules and Regulations]
[Pages 20172-20207]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2016-06563]



[[Page 20171]]

Vol. 81

Wednesday,

No. 66

April 6, 2016

Part IV





Environmental Protection Agency





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40 CFR Parts 60 and 63





National Emission Standards for Hazardous Air Pollutants From Coal- and 
Oil-Fired Electric Utility Steam Generating Units and Standards of 
Performance for Fossil-Fuel-Fired Electric Utility, Industrial-
Commercial-Institutional, and Small Industrial-Commercial-Institutional 
Steam Generating Units; Technical Correction; Final Rule

  Federal Register / Vol. 81 , No. 66 / Wednesday, April 6, 2016 / 
Rules and Regulations  

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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Parts 60 and 63

[EPA-HQ-OAR-2009-0234 and EPA-HQ-OAR-2011-0044; FRL-9942-28-OAR]
RIN 2060-AS41


National Emission Standards for Hazardous Air Pollutants From 
Coal- and Oil-Fired Electric Utility Steam Generating Units and 
Standards of Performance for Fossil-Fuel-Fired Electric Utility, 
Industrial-Commercial-Institutional, and Small Industrial-Commercial-
Institutional Steam Generating Units; Technical Correction

AGENCY: Environmental Protection Agency (EPA).

ACTION: Final rule; technical corrections.

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SUMMARY: This action finalizes the technical corrections that the 
Environmental Protection Agency (EPA) proposed on February 17, 2015, to 
correct and clarify certain text of the EPA's regulations regarding 
``National Emission Standards for Hazardous Air Pollutants from Coal- 
and Oil-fired Electric Utility Steam Generating Units and Standards of 
Performance for Fossil-Fuel-Fired Electric Utility, Industrial-
Commercial-Institutional, and Small Industrial-Commercial-Institutional 
Steam Generating Units''. We are also taking final action to remove the 
rule provision establishing an affirmative defense for malfunction.

DATES: The effective date of this rule is April 6, 2016.

ADDRESSES: Docket. The EPA has established two dockets for this action: 
Docket ID No. EPA-HQ-OAR-2011-0044 (new source performance standards 
(NSPS) action) and Docket ID No. EPA-HQ-OAR-2009-0234 (Mercury and Air 
Toxics Standards (MATS) action). All documents in the dockets are 
listed in the http://www.regulations.gov index. Although listed in the 
index, some information is not publicly available (e.g., confidential 
business information or other information whose disclosure is 
restricted by statute). Certain other material, such as copyrighted 
material, will be publicly available only in hard copy form. Publicly 
available docket materials are available either electronically in 
http://www.regulations.gov or in hard copy at the EPA Docket Center, 
Room 3334, EPA WJC West Building, 1301 Constitution Avenue NW., 
Washington, DC 20004. The Public Reading Room is open from 8:30 a.m. to 
4:30 p.m., Monday through Friday, excluding legal holidays. The 
telephone number for the Public Reading Room is (202) 566-1744, and the 
telephone number for the Air Docket is (202) 566-1742.

FOR FURTHER INFORMATION CONTACT: For questions about the MATS action: 
Mr. Jim Eddinger, Energy Strategies Group, Sector Policies and Programs 
Division (D243-01), Office of Air Quality Planning and Standards, U.S. 
Environmental Protection Agency, Research Triangle Park, North Carolina 
27711; telephone number: (919) 541-5426; fax number (919) 541-5450; 
email address: [email protected]. For questions about the NSPS 
action: Mr. Christian Fellner, Energy Strategies Group, Sector Policies 
and Programs Division (D243-01), Office of Air Quality Planning and 
Standards, U.S. Environmental Protection Agency, Research Triangle 
Park, North Carolina 27711; telephone number: (919) 541-4003; fax 
number (919) 541-5450; email address: [email protected].

SUPPLEMENTARY INFORMATION: 

A. How can I get copies of this document and other related information?

    This Federal Register document and the document titled ``Summary of 
Public Comments and Responses: MATS and Utility NSPS Technical 
Corrections'' (TC RTC) are available in the dockets the EPA established 
under Docket ID No. EPA-HQ-OAR-2009-0234 and Docket ID No. EPA-HQ-OAR-
2011-0044. The TC RTC is available in both the MATS and Utility NSPS 
dockets by conducting a search of the title ``Summary of Public 
Comments and Responses: MATS and Utility NSPS Technical Corrections.'' 
In addition to being available in the docket, electronic copies of 
these documents are available on the www.regulations.gov Web site. This 
Federal Register document and the TC RTC can also be found on the EPA's 
Technology Transfer Network (TTN) Web site at http://www.epa.gov/ttn/atw/utility/utilitypg.html.

B. Judicial Review

    Under CAA section 307(b)(1), judicial review of this final rule is 
available only by filing a petition for review in the U.S. Court of 
Appeals for the District of Columbia Circuit by June 6, 2016. Under CAA 
section 307(d)(7)(B), only an objection to this final rule that was 
raised with reasonable specificity during the period for public comment 
can be raised during judicial review. Note, under CAA section 
307(b)(2), the requirements established by this final rule may not be 
challenged separately in any civil or criminal proceedings brought by 
the EPA to enforce these requirements.

I. Background

    The final Clean Air Act (CAA) rules published in the Federal 
Register on February 16, 2012 (77 FR 9303), establish national emission 
standards for hazardous air pollutants (NESHAP) from coal- and oil-
fired electric utility steam generating units (EGUs), referred to as 
``MATS,'' and NSPS for fossil-fuel-fired electric utility, industrial-
commercial-institutional, and small industrial-commercial-institutional 
steam generating units, referred to as the ``Utility NSPS''.
    In the February 17, 2015, Federal Register (80 FR 8442), the EPA 
proposed to correct certain regulatory text. The proposed corrections 
were categorized generally as follows: (a) Resolution of conflicts 
between preamble and regulatory text, (b) corrections that were 
inadvertently not made that the EPA stated it would make in response to 
comments, and (c) clarification of language in regulatory text. In the 
proposed rule, the EPA identified each proposed technical correction to 
the regulatory text as found in the Code of Federal Regulations (i.e., 
40 CFR). Table 1 of this preamble lists the proposed revisions to the 
regulatory text that the EPA is finalizing. In Table 2 below, the EPA 
lists additional changes that the Agency determined were necessary to 
conform to changes the Agency included in the proposed rule.

[[Page 20173]]



  Table 1--Summary of Proposed Technical Corrections and Clarifications
                             Being Finalized
------------------------------------------------------------------------
  Section of subpart Da  (40 CFR     Description of correction  (40 CFR
             part 60)                             part 60)
------------------------------------------------------------------------
40 CFR 60.48Da(f).................  Revise procedures for calculating
                                     compliance with the NSPS daily
                                     average particulate matter (PM)
                                     emission limit using PM continuous
                                     emission monitoring system (CEMS).
------------------------------------------------------------------------


 
 Section of subpart UUUUU  (40 CFR   Description of correction  (40 CFR
             part 63)                             part 63)
------------------------------------------------------------------------
40 CFR 63.9983(a).................  Revise to clarify that MATS does not
                                     apply to either major or area
                                     source combustion turbines, except
                                     for integrated gasification
                                     combined cycle (IGCC) units.
40 CFR 63.9983(b) and (c).........  Revise consistent with the
                                     definitional changes in 40 CFR
                                     63.10042.
40 CFR 63.9983(e).................  Add to clarify applicability to
                                     units meeting the definition of a
                                     natural gas-fired EGU in MATS, and,
                                     because they combust greater than
                                     10 percent biomass, also meet the
                                     definition of a biomass-fired
                                     boiler in the Industrial Boiler
                                     NESHAP (subpart DDDDD).
40 CFR 63.9991(c)(1) and (2)......  Revise to clarify the conditions
                                     that are required in order to use
                                     the alternate sulfur dioxide (SO2)
                                     limit.
40 CFR 63.10000(c)(1)(i)(A) and     Revise to clarify the provisions of
 63.10005(h).                        units designated as being low
                                     emitting EGUs (LEE) when an acid
                                     gas scrubber and a bypass stack are
                                     present.
40 CFR 63.10000(c)(1)(i)(C).......  Add to allow EGUs the ability to
                                     seek LEE status if their bypass
                                     stacks that are able to measure
                                     emissions and to allow EGUs with
                                     LEE status the ability to bypass
                                     emissions control devices during
                                     emergency periods.
40 CFR 63.10000(c)(2)(iii)........  Revise to state that EGU choosing to
                                     use quarterly testing and
                                     parametric monitoring for hydrogen
                                     fluoride (HF) or hydrogen chloride
                                     (HCl) compliance must include the
                                     continuous monitoring systems (CMS)
                                     in their site-specific monitoring
                                     plans.
40 CFR 63.10000(m)................  Add to clarify that EGUs choosing to
                                     meet the work practice standards
                                     contained in paragraph (2) of the
                                     definition of startup may verify,
                                     instead of certify, monitoring
                                     systems used to meet the work
                                     practice standards.
40 CFR 63.10001...................  Revise to remove the affirmative
                                     defense provisions.
40 CFR 63.10005(a)................  Revise to clarify that different
                                     compliance demonstrations may
                                     require different and additional
                                     types of data collection and to
                                     clarify the date by which
                                     compliance must be demonstrated for
                                     existing EGUs.
40 CFR 63.10005(a)(2).............  Revise to clarify the date by which
                                     compliance must be demonstrated for
                                     EGUs using CMS or sorbent trap
                                     monitoring systems.
40 CFR 63.10005(a)(2)(i)..........  Revise to clarify applicability of
                                     the provision to both the 30- and
                                     90-boiler operating day performance
                                     testing requirements.
40 CFR 63.10005(b)(6).............  Add to clarify the date EGUs must
                                     begin conducting required stack
                                     tests when stack test data
                                     collected prior to the applicable
                                     compliance date are submitted to
                                     satisfy initial performance test.
40 CFR 63.10005(d)(3) and           Revise to more clearly state when
 (d)(4)(i).                          compliance must be demonstrated.
40 CFR 63.10005(f)................  Revise to clarify when sources must
                                     complete the initial tune-up after
                                     the compliance date, and the timing
                                     for subsequent tune-ups when the
                                     initial tune-up is conducted prior
                                     to the compliance date.
40 CFR 63.10005(h)(3).............  Revise to clarify that the alternate
                                     30- and 90-day averaging provisions
                                     are both applicable to mercury (Hg)
                                     emission limits.
40 CFR 63.10005(i)(4).............  Revise to delete paragraphs (iii)
                                     and (iv). The identified test
                                     methods are not for determining
                                     fuel moisture content, as required
                                     in the provision.
40 CFR 63.10006(f)................  Revise to specify EGU operational
                                     status with respect to performance
                                     testing; the requirements if the
                                     performance testing schedule is
                                     missed; and intervals between
                                     performance tests.
40 CFR 63.10009(a)(2) and           Revise to clarify that the 90-boiler
 (a)(2)(i).                          operating day averaging period is
                                     an option for Hg emissions from non-
                                     low rank virgin coal-fired EGUs.
40 CFR 63.10009(b)(1).............  Revise to clarify group eligibility
                                     equations 1a and 1b.
40 CFR 63.10009(b)(2), (b)(3),      Revise to correct the term ``gross
 (f)(2), (g)(1), (g)(2), and         electric output'' to ``gross
 (j)(1)(ii).                         output'' which is the term defined
                                     in 40 CFR 63.10042.
40 CFR 63.10009(f)................  Revise to clarify the conditions for
                                     determining the ability of the
                                     emissions averaging group to meet
                                     the emissions limit and to clarify
                                     use of the alternate Hg emission
                                     limit.
40 CFR 63.10010(a)(4).............  Revise to add requirement to route
                                     exhaust gases that bypass emissions
                                     control devices through stacks that
                                     contain monitoring so that
                                     emissions can be measured and to
                                     clarify that hours that a bypass
                                     stack is in use are to be counted
                                     as hours of deviation from
                                     monitoring requirements.
40 CFR 63.10010(f)(3).............  Revise to clarify that 30-boiler
                                     operating day rolling averages are
                                     based only on valid hourly SO2
                                     emission rates.
40 CFR 63.10010(h)(6)(i) and (ii),  Revise to clarify that data
 (i)(5)(i)(A) and (B), and           collected during certain periods
 (j)(4)(i)(A) and (B).               are not to be included in
                                     compliance assessments but such
                                     periods are to be included in
                                     annual deviation reports.
40 CFR 63.10010(j)(l)(i)..........  Revise to replace the incorrect
                                     reference to Sec.   63.7(e) with
                                     the correct reference to Sec.
                                     63.8(d)(2).
40 CFR 63.10010(l) and (l)(4).....  Revise to clarify that EGU owners or
                                     operators who choose to meet the
                                     work practice standards contained
                                     in paragraph (2) of the definition
                                     of startup may verify, instead of
                                     certify, monitoring systems used.
40 CFR 63.10011(b)................  Revise to remove the incorrect
                                     reference to Table 4 and to replace
                                     the incorrect reference to Table 7
                                     with the correct reference to Table
                                     6.
------------------------------------------------------------------------


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  Table 1--Summary of Proposed Technical Corrections and Clarifications
                       Being Finalized--Continued
------------------------------------------------------------------------
 Section of subpart UUUUU  (40 CFR   Description of correction  (40 CFR
             part 63)                             part 63)
------------------------------------------------------------------------
40 CFR 63.10011(c)(1) and (2).....  Revise to clarify the date by which
                                     compliance must be demonstrated by
                                     EGUs that use CEMS or sorbent trap
                                     monitoring systems and to clarify
                                     in 40 CFR 63.10011(c)(1) that the
                                     alternate Hg emission limit may be
                                     used.
40 CFR 63.10011(e)................  Revise to replace ``according to''
                                     with ``in accordance with.''
40 CFR 63.10011(g)(4)(v)(A) and     Revise to clarify our intent by
 Table 3.                            changing ``to the maximum extent
                                     possible'' to ``to the maximum
                                     extent possible, taking into
                                     account boiler or control device
                                     integrity.''
40 CFR 63.10020(e)................  Revise to clarify that it applies
                                     only to EGU owners or operators who
                                     choose to meet the work practice
                                     standards contained in paragraph
                                     (2) of the definition of startup.
                                     In addition, the undefined term
                                     ``electrical load'' has been
                                     replaced with the defined term
                                     ``gross output'' and the incorrect
                                     terms ``liquid to fuel ratio'' and
                                     ``the differential pressure of the
                                     liquid'' have been replaced with
                                     the correct terms ``liquid to flue
                                     gas ratio'' and ``the pressure drop
                                     across the scrubber.''
40 CFR 63.10021(d)(3).............  Revise to clarify the type of
                                     monitoring that is to be used to
                                     demonstrate compliance.
40 CFR 63.10021(e)................  Revise to clarify the condition that
                                     allows delay of burner inspections
                                     for initial tune-ups.
40 CFR 63.10021(e)(9).............  Revise to clarify the dates that
                                     tune-ups must be reported.
40 CFR 63.10023(b) and Table 6....  Revise to clarify that all EGUs
                                     using PM continuous parametric
                                     monitoring systems (CPMS) for
                                     compliance purposes are to follow
                                     the same procedure for determining
                                     the operating limit.
40 CFR 63.10030(e)(1).............  Revise to replace the phrase
                                     ``identification of which
                                     subcategory the source is in'' with
                                     ``identification of the subcategory
                                     of the source.''
40 CFR 63.10030(e)(7)(i)..........  Revise to delete and reserve since
                                     subsequent performance tests are
                                     not part of the Notification of
                                     Compliance Status.
40 CFR 63.10030(e)(7)(iii)........  Add to establish the procedures by
                                     which an EGU owner or operator may
                                     switch between mass per heat input
                                     and mass per gross output emission
                                     limits.
40 CFR 63.10030(e)(8)(i)..........  Revise to clarify that it applies
                                     only to EGU owners or operators who
                                     choose to meet the work practice
                                     standards contained in paragraph
                                     (2) of the definition of startup.
                                    Revise to clarify that PM control
                                     device efficiencies and PM emission
                                     rates are those of periods other
                                     than startup and shutdown periods.
40 CFR 63.10030(e)(8)(ii).........  Revise to remove the requirement for
                                     use of an independent professional
                                     engineer.
40 CFR 63.10030(f)................  Revise to add notification
                                     requirements for EGUs that move in
                                     and out of MATS applicability.
40 CFR 63.10031(c)(4).............  Revise to clarify the reporting
                                     requirements for EGU tune-ups.
40 CFR 63.10031(c)(5).............  Revise to clarify that it applies
                                     only to EGU owners or operators who
                                     choose to meet the work practice
                                     standards contained in paragraph
                                     (2) of the definition of startup.
40 CFR 63.10031(c)(6).............  Revise to add emergency bypass
                                     reporting for EGUs with LEE status.
40 CFR 63.10032(f)................  Revise to clarify that the
                                     requirements of Sec.
                                     63.10032(f)(1) apply only to those
                                     EGU owners or operators who choose
                                     to meet the work practice standards
                                     contained in paragraph (1) of the
                                     definition of startup, while the
                                     requirements of Sec.
                                     63.10032(f)(2) apply only to those
                                     EGU owners or operators who choose
                                     to meet the work practice standards
                                     contained in paragraph (2) of the
                                     definition of startup.
40 CFR 63.10042...................  The definitions of ``Coal-fired
                                     electric utility steam generating
                                     unit,'' ``Coal refuse,'' ``Fossil
                                     fuel-fired,'' ``Integrated
                                     gasification combined cycle
                                     electric utility steam generating
                                     unit or IGCC,'' ``Limited-use
                                     liquid oil-fired subcategory,''
                                     ``Natural gas-fired electric
                                     utility steam generating unit,''
                                     and ``Oil-fired electric utility
                                     steam generating unit'' are revised
                                     to clarify the period of time to be
                                     included in determining the
                                     source's applicability to the MATS.
                                    A definition of ``neural network''
                                     is added because the term is used
                                     in 40 CFR 63.10005(f), 63.10006(i),
                                     and 63.10021(e) and Table 3 to
                                     subpart UUUUU of Part 63 but is not
                                     defined.
Table 1 to subpart UUUUU of part    Revise to correct the term ``gross
 63.                                 electric output'' to ``gross
                                     output'' which is the term defined
                                     in 40 CFR 63.10042.
Table 2 to subpart UUUUU of part    Revise to correct the term ``gross
 63.                                 electric output'' to ``gross
                                     output'' which is the term defined
                                     in 40 CFR 63.10042. Provision 1(c)
                                     (the Hg limit for EGUs in the
                                     subcategory ``unit designed for
                                     coal >=8,300 Btu/lb'') is also
                                     revised to clarify the
                                     applicability of the alternate 90-
                                     boiler operating day compliance
                                     option.
Table 3 to subpart UUUUU of part    Revise as described earlier to
 63.                                 clarify the term ``maximum extent
                                     possible.''.
Table 4 to subpart UUUUU of part    Revise to clarify that existing as
 63.                                 well as new EGUs using PM CPMS
                                     share the same procedures for
                                     developing operating limits.
Table 5 to subpart UUUUU of part    Revise to clarify that when using
 63.                                 Method 29, the metals matrix spike
                                     and recovery levels are to be
                                     reported.
Table 6 to subpart UUUUU of part    Revise to clarify that existing, as
 63.                                 well as new, EGUs using PM CPMS
                                     share the same procedures for
                                     developing operating limits.
Table 8 to subpart UUUUU of part    Revise to clarify that compliance
 63.                                 reports are to include information
                                     required by 40 CFR 63.10031(c)(5)
                                     and (6).
Table 9 to subpart UUUUU of part    Revise to correct an inadvertent
 63.                                 omission of 30-day notification
                                     requirements of 40 CFR 63.9.
Paragraphs 4.1.1.3 and 5.1.2.3 and  Revise to adjust Hg CEMS language
 Tables A-1 and A-2 to appendix A.   regarding converters.
Paragraph 7.1.2.5 to appendix A...  Add to require that owners or
                                     operators flag EGUs that are part
                                     of emission averaging groups.
Paragraph 3.2.1.2.1 of appendix A.  Revise to specifically indicate that
                                     Hg gas generators and cylinders are
                                     allowed.
Paragraphs 4.1.1.1, Table A-1,      Revise to exclude use of oxidized Hg
 Table A-2, 5.1.2.1, and 4.1.1.3     gas standards for daily calibration
 of appendix A.                      of Hg CEMS.
Paragraph 5.1.2.3 of appendix A...  Revise to make the weekly single
                                     level system integrity check
                                     mandatory.
------------------------------------------------------------------------


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  Table 1--Summary of Proposed Technical Corrections and Clarifications
                       Being Finalized--Continued
------------------------------------------------------------------------
 Section of subpart UUUUU  (40 CFR   Description of correction  (40 CFR
             part 63)                             part 63)
------------------------------------------------------------------------
Paragraphs 4.1.1.5.2, Table A-1,    Revise to provide an alternative
 Table A-2, and 4.1.1.5 of           relative accuracy test audit (RATA)
 appendix A.                         procedure for EGUs with low
                                     emissions.
Paragraph 5.2.1 of appendix A.....  Revise to correct the number of days
                                     for sorbent trap use from 14 to 15.
Paragraph 6.2.2.3 of appendix A...  Revise to clarify that the 90-day
                                     alternative Hg standard may be used
                                     and that electrical output is gross
                                     output.
Paragraph 7.1.2.6 of appendix A...  Add to clarify that EGU owners or
                                     operators are to keep records of
                                     their EGUs that constitute
                                     emissions averaging groups.
Paragraphs 2.1, 2.3, 2.3.1, 2.3.2,  Revise to clarify that use of
 3.1, 3.2, 3.3, 5, 5.1, 5.2, and     Performance Specification (PS) 18,
 5.3 of appendix B.                  when promulgated, will be allowed.
Paragraph 5.4 of appendix B.......  Add as part of the renumbering due
                                     to the addition of PS 18.
Paragraph 8 of appendix B.........  Revise to accommodate use of PS 18.
Paragraphs 10.1.8, 10.1.8.1,        Revise as part of the renumbering
 10.1.8.1.1, and 10.1.8.1.2 of       due to the addition of PS 18.
 appendix B.
Paragraph 10.1.8.1.3 of appendix B  Revise to clarify that records of
                                     relative accuracy audits (RAAs) are
                                     also required.
Paragraphs 10.1.8.2, 10.1.8.1.2.1,  Revise to clarify the quarterly gas
 and 10.1.8.1.2.2 of appendix B.     audit recordkeeping requirements
                                     for PS 15 and the quarterly data
                                     accuracy assessments for PS 18
                                     (which are reserved).
Paragraph 11.4 of appendix B......  Revise to replace the incorrect
                                     abbreviation ``i.e.'' with
                                     ``e.g.''.
Paragraph 11.4.2 of appendix B....  Revise to specify the requirements
                                     of the daily beam intensity checks
                                     for EGUs using PS 18.
Paragraph 11.4.3 of Appendix B....  Revise to reflect the reporting
                                     requirements for PS 15.
Paragraph 11.4.4 of appendix B....  Revise to reserve the reporting
                                     requirements for quarterly
                                     parameter verification checks for
                                     PS 18.
Paragraphs 11.4.4.1, 11.4.5,        Add to reserve the reporting
 11.4.5.1, 11.4.6, 11.4.6.1 of       requirements for quarterly gas
 appendix B.                         audit information and for quarterly
                                     dynamic spiking for PS 18.
Paragraph 11.4.7 of appendix B....  Add to include reporting
                                     requirements for RAAs.
Paragraphs 11.4.7.1 through         Add as part of the renumbering due
 11.4.7.13 of appendix B.            to the addition of PS 18.
Paragraph 11.5.3.4 of appendix B..  Revise to include reporting
                                     requirements for beam intensity
                                     checks for PS 18.
------------------------------------------------------------------------

    Most of the corrections and clarifications remain the same as 
presented in the proposed correction document and those changes are 
being finalized without further discussion. However, the EPA has made 
some changes in this final rule after consideration of the public 
comments received on the proposed correction document. The changes are 
to clarify applicability and implementation issues associated with 
proposed changes, and the significant changes are discussed below in 
this preamble. A summary of the comments received and our responses 
thereto is contained in the document ``Summary of Public Comments and 
Responses: MATS and Utility NSPS Technical Corrections'' located in the 
dockets for these rulemakings.

II. Significant Changes Since Proposal

    This section of the preamble summarizes the significant changes 
made to the proposed corrections and clarifications.
    1. Section 63.9984(f) is revised to add ``or the EGU's otherwise 
applicable compliance date established by the EPA or the state.'' A 
commenter stated that the EPA's proposed revision, which was adding 
``the date that compliance must be demonstrated, as given'' in Sec.  
63.9984, to the initial compliance requirements in Sec.  63.10005(a) 
for existing EGUs, does not effectively clarify the date that 
compliance must be demonstrated due to its reference to Sec.  63.9984 
and paragraph (f) of Sec.  63.9984 because Sec.  63.9984(b) specifies a 
compliance date of April 16, 2015 for existing EGUs. Also, Sec.  
63.9984(f), which states the dates by which compliance must be 
demonstrated, refers to Sec.  63.9984(b). Therefore, we revised Sec.  
63.9984(f) because specifying a date for existing EGUs to demonstrate 
compliance is confusing for existing sources that have been granted a 
compliance extension.
    2. Section 63.10000(n) is added to address comments that noted the 
proposed technical corrections did not address the permanent conversion 
to natural gas or biomass consistent with the proposals outlined in the 
February 17, 2015 preamble. In the preamble (see 80 FR 8447), we stated 
``The EPA is also proposing that sources that permanently convert to 
natural gas or biomass after the compliance date are no longer subject 
to MATS, notwithstanding the coal or oil usage the previous 3 calendar 
years.'' However, we inadvertently did not include the necessary 
language to address permanent conversions in the proposed regulatory 
text. For that reason, we are revising paragraph (n) to incorporate the 
proposed change as outlined in the preamble to the proposed rule.
    3. The proposal to revise Sec.  63.10005(b)(1) to change the time 
period allowed for existing EGUs to use stack test data collected prior 
to the applicable compliance date has been withdrawn. Several 
commenters did not support the proposed revision to change the window 
in which initial compliance can be demonstrated, and said that EGUs 
should be allowed to demonstrate initial compliance using stack tests 
conducted on or after April 16, 2014. Commenters said the EPA's 
proposed change is unfair, renders investments in stack testing 
useless, and requires companies to perform new, unnecessary initial 
compliance testing. For these reasons, and because the Agency believes 
earlier stack tests may be representative under certain circumstances, 
the EPA is not making the proposed change.
    4. Section 63.10006(f) is revised to: (1) Correct the minimum time 
between annual performance tests (from 370 to 320 calendar days); (2) 
clarify the minimum time between annual sorbent trap mercury testing 
for 30-boiler operating day low emitting EGU (LEE) retests (also 320 
calendar days); and (3) provide the minimum time between annual sorbent 
trap mercury testing for 90-boiler operating day LEE retests (230 
calendar days). Commenters correctly stated that the 370-day interval 
for annual tests was a typographical error, as they would expect the 
interval to be 365 days or less. Commenters expressed concerns that, 
while the proposed revised Sec.  63.10006(f) specified the time

[[Page 20176]]

periods between annual performance tests, it did not specify the time 
periods between annual sorbent trap mercury testing for either the 30-
boiler operating day averaging periods or the 90-boiler operating day 
averaging periods. The three revisions, listed above, being made to 
Sec.  63.10006(f) address the commenters' concerns. In addition, Sec.  
63.10010(i)(2)(i) and (ii) is revised to clarify the time periods 
between quarterly, annual, and three year testing for particulate 
matter continuous emissions monitoring system (PM CEMS) audits.
    5. Section 63.10009(b)(1) is revised to clarify group eligibility 
equations 1a and 1b. The purpose of the group eligibility equations is 
to provide EGU owners or operators a quick method for demonstrating 
initial compliance with the emission limits for all units participating 
in the emission averaging group using the maximum rated heat input or 
gross output of each unit and the results of the initial compliance 
demonstrations. Commenters stated that the EPA proposed to drop the 
double summation in the denominator, which is a correct step. However, 
the commenters indicated they do not understand what the Agency was 
thinking with respect to adding the ``qj'' term in both the 
numerator and denominator and that the EPA defined ``qj'' to 
be the hours in the averaging period (720 for 30-day averages and 2,160 
for 90-day averages) because the term's presence in both the numerator 
and denominator cancels out and has no effect. Commenters also stated 
that they do not agree that the newly proposed group averaging 
eligibility Equation 1a is more useful than the original equation. 
Commenters said both the original equation and the newly proposed 
equation are flawed and, thus, produce incorrect results. Commenters 
said corrections need to be made to either equation that the EPA wants 
to use. Commenters said the stack testing components of the equation 
for each unit that is tested need to be weighted the same as units that 
use continuous monitoring in order for any equation to produce correct 
calculations. Commenters said the original equation works for the 
continuous monitoring components, but is flawed because it does not 
properly weight the stack testing components, and the newly proposed 
equation is flawed on both fronts. Based on the commenters' concerns, 
the equations have been revised so that individual EGU characteristics, 
whether from continuous emission monitoring systems (CEMS) or stack 
testing results, are easier to input. We agree that the added 
``qj'' term and ``rk'' term have no effect, and 
they have been deleted. We are also deleting the ``n'' term since 
Equations 1a and 1b are to demonstrate initial compliance based on 
using the initial compliance results and not continuous compliance that 
is based on an averaging period. We have revised some of the terms' 
descriptions to clarify that the emission rates used are those 
determined during the initial compliance demonstration.
    6. Section 63.10009(e), (g), and (j)(2) are revised to require 
compliance with the weighted average emissions rate at all times 
following the date that emissions averaging begins. A commenter argued 
that the EPA must also revise these sections to remove the specifically 
identified dates (e.g., April 16, 2015 and February 16, 2015). We agree 
that the dates within Sec.  63.10009(e), (g), and (j)(2) should be 
removed, and the dates have been replaced with ``the date that you 
begin emission averaging.''
    7. Section 63.10010(h)(6)(i), (i)(5)(i)(A), and (j)(4)(i)(A) and 
(B) are revised to clarify when monitoring system quality assurance or 
quality control activities are to be reported. Commenters said Sec.  
63.10010(h)(6)(i), (i)(5)(i)(A), and (j)(4)(i)(A) and (B) specify what 
data from particulate matter (PM) continuous parameter monitoring 
system (CPMS), PM CEMS, and hazardous air pollutants (HAP) metal CEMS 
must be excluded from compliance determinations and that the EPA 
proposed to separate the language regarding deviation reporting that 
currently appears at the end of these provisions into a separate 
sentence to ``ease readability.'' The commenter disagreed that the 
proposed revision improves readability and said that, to the contrary, 
by separating out the sentence, the EPA implies that the periods when 
data are not collected because of monitoring system malfunctions, 
repairs, required quality assurance or quality control, as well as 
periods when a monitoring system is out of control, are deviations from 
monitoring requirements, which they are not. The commenter is 
incorrectly interpreting the proposed change. Periods when data are not 
collected because of monitoring system malfunctions are deviations. The 
required quality assurance or quality control activities that are 
deviations from monitoring requirements are, as stated in Sec.  
63.10010(h)(6)(i), (i)(5)(i)(A), and (j)(4)(i)(A) and (B), those 
conducted during monitoring systems malfunctions.
    8. Section 63.10011(g)(4)(v)(A) is revised to change the proposed 
language ``to the maximum extent practicable'' back to the language 
``to the maximum extent possible'' as in the final rule. Commenters 
said the requirement to use clean fuels ``to the maximum extent 
practicable'' does not even address the level of toxic emissions during 
startup, let alone reduce them to the maximum extent achievable as is 
required under CAA section 112(d)(2). Commenters said, perhaps most 
importantly, that the EPA's proposed change impermissibly assumes that 
existing older boilers and control devices are not capable of being 
upgraded--despite Congress' mandate in CAA section 112(d)(2)-(3) that 
emissions standards and work practices reflect what is achievable and 
actually being achieved by the best-performing sources. Commenters said 
further, under CAA section 112(d), it is the Administrator's duty to 
establish standards to achieve the required emissions reductions--not 
the duty of owners and operators. Commenters said the EPA's purported 
work practices impermissibly allow operators themselves to determine 
the standards and their own emission reductions achieved (or not) by 
the requirements. Commenters said the EPA's proposed change leaves it 
up to each operator to determine the amount of clean fuel use that 
represents the ``maximum extent practicable,'' and leaves it up to each 
operator to determine what qualifies as a ``consideration such as 
boiler or control device integrity.'' Commenters said that even though 
the requirement for clean fuels states that EGUs must have sufficient 
clean fuel capacity to engage and operate PM control devices within 1 
hour of adding the primary fuel (and even though a separate work 
practice requires PM controls to be engaged and operated within 1 
hour), these requirements do not establish whether and to what point 
EGUs must actually use clean fuels in startups. These comments 
primarily concern issues that the EPA did not reopen in the proposed 
document. Because those issues were not reopened, the EPA did not 
respond to these comments. We did propose to change Sec.  
63.10011(g)(4)(v)(A) as the commenter states. We continue to believe 
that the use of clean fuels during startup must be maximized to reduce 
HAP emissions and have reconsidered the proposed change of ``possible'' 
to ``practicable.'' We believe ``possible'' is a more enforceable 
standard. The final change to Sec.  63.10011(g)(4)(v)(A) is: ``to the 
maximum extent possible, taking into account considerations such as 
boiler or control device integrity,

[[Page 20177]]

throughout the startup period.'' This language is also included in 
section 4 of Table 3, to clarify that this provision applies during 
periods of shutdown.
    The EPA is not finalizing the proposed change because we have 
determined that requiring clean fuel use to the maximum extent 
``possible'' is more enforceable than the proposed change to 
``practicable'', and the Agency believes it is critical that the work 
practice be enforceable to ensure that sources use as much clean fuel 
with its inherently low HAP content as possible when a source's 
controls are not yet fully engaged. At the same time, we believe 
operators must be able to consider the integrity of the EGU system when 
determining the clean fuel use that is ``possible'' for a given unit. 
We believe the final rule addresses both considerations.
    9. Section 63.10030(e)(8)(iii) is added to allow EGU owners or 
operators the ability to switch between paragraphs 1 and 2 of the 
startup definition. Commenters requested that switching between 
paragraphs of the definition of startup not be prohibited. We have no 
objection to such switching provided certain criteria are met. Just as 
we had not considered that EGU owners or operators would want to switch 
between mass per year heat input emission limits and mass per gross 
output emission limits, but proposed to allow such changes provided 
certain criteria are met, we did not consider that an owner or operator 
would want to switch between the startup definitions for the EGU. Given 
the commenter's specific request and the EPA's conditional approval 
based on the already existing model given in Sec.  
63.10030(e)(7)(iii)(A), Sec.  63.10030(e)(8)(iii) is added to the rule. 
This new section allows EGU owners or operators the ability to switch 
between paragraphs 1 and 2 of the startup definition provided, among 
other things, that the EGUs involved in the switch are identified, that 
a request is submitted 30 days prior to the anticipated switch, that 
the request contains certification that all previous plans, such as 
monitoring and emissions averaging, are revised, that records are 
maintained, and that the new definition is not used until the next 
reporting period after receipt of written acknowledgement from the 
Administrator or the delegated authority of the switch.
    10. Section 63.10031(c)(4) is revised to clarify that the ``date'' 
of the tune-up is the date the tune-up provisions specified in Sec.  
63.10021(e)(6) and (7) are completed. Commenters noted that there will 
not necessarily be a single date associated with completion of an EGU's 
tune-ups conducted under Sec.  63.10021(e) and suggested that, related 
to the possibility of a delayed burner inspection, the Agency make it 
clear that compliance with all requirements besides the burner 
inspection must occur by the compliance demonstration date, but that 
the burner inspection may be delayed, and to revise the provision to 
recognize that as a result, performance of subsequent inspections and 
tune-ups may be on a separate 36-month track and some EGUs may have 
``dates'' rather than a ``date'' for completion of requirements. 
Regardless of when the burner inspection is conducted, the tune-up is 
considered to have been conducted on the date the combustion 
optimization is completed. The purpose of the tune-up is the 
optimization of the combustion to minimize organic HAP, carbon 
monoxide, and nitrogen oxides (NOX) and to improve or return 
the unit to its design combustion efficiency (i.e., Sec.  
63.10021(e)(6) and (7)). We realize that EGUs may need to be taken off-
line to conduct an inspection of burners. So, we allow that inspection 
to be delayed, or as Sec.  63.10021(e) is revised, to be performed 
prior to the tune-up. Therefore, subsequent tune-ups must be performed 
within 36 months from when the previous tune-up (i.e., the requirements 
of Sec.  63.10021(e)(6) and (7)) was completed, and the source must 
conduct the next burner inspection on a similar schedule.
    11. Section 63.10031(c)(7) is added to include the reporting 
requirements that have been removed from Sec.  63.10030(e)(7)(i). A 
commenter said that there is no reason to submit Notification of 
Compliance Status (NOCS) for ongoing 3-year tests that are performed to 
demonstrate that LEE status is maintained, so the proposed language in 
Sec.  63.10030(e)(7)(i) should be revised. We agree that not only the 
ongoing 3-year LEE retests, but also the annual and quarterly LEE 
retests and annual retests that are performed to establish operating 
limits, should not be submitted as NOCS. According to the introductory 
text of Sec.  63.10030(e), the NOCS is required only for reporting 
initial compliance. Therefore, Sec.  63.10030(e)(7)(i) has been removed 
and reserved, and the reporting requirements in Sec.  63.10030(e)(7)(i) 
have been moved to a new place, i.e., Sec.  63.10031(c)(7), and are 
part of the compliance report requirements. Likewise, the compliance 
certification and deviation information requirements in Sec.  
63.10030(e)(5) and (e)(6) apply for compliance reports and are 
replicated in new Sec.  63.10031(c)(8) and (9), and each of these 
paragraphs is included in the introductory text in Sec.  63.10030(c) 
and in Table 8.
    12. The definitions of ``Coal-fired electric utility steam 
generating unit,'' ``Fossil fuel-fired,'' ``Limited-use liquid oil-
fired subcategory,'' and ``Oil-fired electric utility steam generating 
unit'' in Sec.  63.10042 are further revised to clarify the period of 
time to be included in determining the source's applicability to the 
MATS.
    One commenter indicated that the proposed rule does not address 
permanent conversion to natural gas or biomass, nor does it make clear 
that, after the first 3 years of compliance, EGUs are required to 
evaluate applicability based on coal or oil usage from the 3 previous 
calendars years on an annual rolling basis. The commenter said that the 
EPA's clarifying proposals are not clearly outlined in the proposed 
revised definitions. The commenter urged the EPA to revise the 
definition in a manner consistent with the proposals outlined in the 
preamble. Several commenters indicated the proposed changes do not 
prevent an EGU from continuing to be subject to MATS for several years 
after a fuel switch.
    We agree that the proposed clarification to the definitions does 
not make it clear that, after the first 3 years of compliance, an EGU 
is required to evaluate applicability based on coal or oil usage from 
the 3 previous calendar years on an annual rolling basis. Thus, we have 
revised the definitions for ``Coal-fired electric utility steam 
generating unit,'' ``Oil-fired electric utility steam generating 
unit,'' and ``Fossil fuel-fired'' to clarify that applicability after 
the first 3 years of compliance will be based on coal or oil usage from 
the 3 previous calendar years on an annual rolling basis.
    Concerning the permanent fuels switch, the EPA explained above that 
it has addressed permanent conversions in Sec.  63.10000(n) of the 
final rule, as discussed in paragraph 2 above.
    13. Appendix A is finalized with all proposed revisions with the 
exception of adding an alternative specification for the relative 
accuracy test audit (RATA) where commenters provided data to support a 
different approach using an absolute value criterion. However, due to 
the current lack of available NIST-traceable elemental Hg gas 
cylinders, owners or operators of EGUs that have purchased/installed Hg 
CEMS that lack integrated elemental Hg gas generators may continue to 
use NIST-traceable oxidized gases for calibration error tests and daily 
checks until such time that NIST-traceable compressed elemental Hg gas 
standards are available and traceable with a combined uncertainty

[[Page 20178]]

(K=2) of 5 percent. Once those standards are available, we will issue a 
notice of availability in the Federal Register. Should NIST-traceable 
oxidized mercury reference gases with a combined uncertainty of 5% 
ultimately be available, we will consider allowing their use for 
calibration error tests and checks.
    14. Appendix B is finalized with all proposed revisions except 
those related to sections 10 and 11 regarding recordkeeping and 
reporting for hydrogen chloride (HCl) CEMS subject to PS 18. Sections 
10 and 11 will be addressed in the upcoming MATS Completion of 
Electronic Reporting Requirements rule. One change has been made that 
was not proposed. A minor technical correction has been made to section 
9.4, requiring the HCl emission rates to be reported to 2 significant 
figures in scientific notation, which is consistent with the way that 
the emission standards are presented in Tables 1 and 2.

III. Other Corrections and Clarifications

    In finalizing the rule, the EPA is addressing several other 
technical corrections and clarifications in the regulatory language 
based on public comments that were received on the February 2015 
proposal that the Agency determined were necessary to conform to 
changes included in the proposed rule, as outlined in Table 2 of this 
preamble.

   Table 2--Summary of Technical Corrections and Clarifications Since
                       February 17, 2015, Proposal
------------------------------------------------------------------------
 Section of subpart UUUUU  (40 CFR   Description of correction  (40 CFR
             part 63)                             part 63)
------------------------------------------------------------------------
40 CFR 63.10000(a)................  Revise this paragraph by adding
                                     ``items 3 and 4'' to clarify which
                                     items in Table 3 must be met.
40 CFR 63.10000(f)................  Revise this paragraph to add
                                     ``Except as provided under
                                     paragraph (n) of this section'' due
                                     to the addition of paragraph (n)
                                     clarifying the applicability of a
                                     permanent conversion to natural gas
                                     or biomass.
40 CFR 63.10000(g)................  Revise this paragraph to add
                                     ``Except as provided under
                                     paragraph (n) of this section'' due
                                     to the addition of paragraph (n)
                                     clarifying the applicability of a
                                     permanent conversion to natural gas
                                     or biomass.
40 CFR 63.10000(i)(1).............  Revise this paragraph to clarify
                                     that an EGU, no longer subject to
                                     MATS, must be in compliance with
                                     applicable CAA section 112 or 129
                                     standards consistent with
                                     paragraphs (g) and (n).
40 CFR 63.10005(a)................  Revise this paragraph to replace the
                                     terms ``electrical'' and
                                     ``electrical load'' with the terms
                                     ``gross'' and ``gross output,''
                                     respectively, to be consistent with
                                     the proposed changes to other
                                     sections.
40 CFR 63.10005(a)(2)(ii).........  Revise this paragraph to replace the
                                     terms ``electrical'' and
                                     ``electrical load'' with the terms
                                     ``gross'' and ``gross output,''
                                     respectively, to be consistent with
                                     the proposed changes to other
                                     sections.
40 CFR 63.10005(b)(4).............  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
40 CFR 63.10005(f)................  Revise to be consistent with EPA's
                                     intent, as explained in the
                                     preamble to the proposed rule, to
                                     only clarify the timing of initial
                                     and subsequent tune-ups.
                                    Revise since specifying the date is
                                     problematic for sources that have
                                     been granted a compliance
                                     extension.
40 CFR 63.10005(h)(3)(i)(D).......  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
40 CFR 63.10005(h)(3)(iii)........  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
40 CFR 63.10007(f)(2).............  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
40 CFR 63.10009(e) and (j)(2).....  Revise since specifying the date is
                                     problematic for sources that have
                                     been granted a compliance
                                     extension.
40 CFR 63.10010(f)(4).............  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
40 CFR 63.10021(h)(1).............  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
Table 5...........................  Revise this table to replace the
                                     term ``electrical'' with the term
                                     ``gross'' to be consistent with the
                                     proposed changes to other sections.
Paragraph 7.1.8.5 of appendix A...  Revise this paragraph to replace the
                                     term ``electrical load'' with the
                                     term ``gross output'' to be
                                     consistent with the proposed
                                     changes to other sections.
------------------------------------------------------------------------

IV. Affirmative Defense for Violation of Emission Standards During 
Malfunction

    The EPA received numerous comments on the affirmative defense to 
civil penalties for violations caused by malfunctions that the EPA 
proposed to remove in the current rule. Several commenters supported 
the removal of the affirmative defense for malfunctions. Other 
commenters opposed the removal of the affirmative defense provision.
    As stated in the February 17, 2015, proposal, the United States 
Court of Appeals for the District of Columbia Circuit vacated an 
affirmative defense in one of the EPA's CAA section 112(d) regulations. 
NRDC v. EPA, No. 10-1371 (D.C. Cir. April 18, 2014) 2014 U.S. App. 
LEXIS 7281 (vacating affirmative defense provisions in CAA section 
112(d) rule establishing emission standards for Portland cement kilns). 
The court found that the EPA lacked authority to establish an 
affirmative defense for private civil suits and held that under the 
CAA, the authority to determine civil penalty amounts in such cases 
lies exclusively with the courts, not the EPA. Specifically, the court 
found: ``As the language of the statute makes clear, the courts 
determine, on a case-by-case basis, whether civil penalties are 
`appropriate.' '' See NRDC, 2014 U.S. App. LEXIS 7281 at *21 (``[U]nder 
this statute, deciding whether

[[Page 20179]]

penalties are `appropriate' in a given private civil suit is a job for 
the courts, not EPA.''). The EPA is finalizing the proposed removal of 
the regulatory affirmative defense provision from MATS. In the event 
that a source fails to comply with an applicable CAA section 112(d) 
standard as a result of a malfunction event, the EPA's ability to 
exercise its case-by-case-enforcement discretion to determine an 
appropriate response provides sufficient flexibility in such 
circumstances as was explained in the preamble to the proposed rule. 
Further, as the D.C. Circuit recognized, in an EPA or citizen 
enforcement action, the court has the discretion to consider any 
defense raised and determine whether penalties are appropriate. Cf. 
NRDC, 2014 U.S. App. LEXIS 7281 at *24 (arguments that violation were 
caused by unavoidable technology failure can be made to the courts in 
future civil cases when the issue arises). The same is true for the 
presiding officer in EPA administrative enforcement actions. For all 
these reasons, this final rule removes the affirmative defense 
provisions.

V. Impacts of This Final Rule

    This action finalizes certain provisions and makes technical and 
clarifying corrections, but does not promulgate substantive changes to 
the February 2012 final MATS (77 FR 9304). Therefore, there are no 
environmental, energy, or economic impacts associated with this final 
action. The impacts associated with MATS are discussed in detail in the 
February 16, 2012, final MATS rule.

VI. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive Orders 
can be found at http://www2.epa.gov/laws-regulations/laws-and-executive-orders.

A. Executive Order 12866: Regulatory Planning and Review and Executive 
Order 13563: Improving Regulation and Regulatory Review

    This action is not a significant regulatory action and was, 
therefore, not submitted to the Office of Management and Budget (OMB) 
for review.

B. Paperwork Reduction Act (PRA)

    This action does not impose any new information collection burden 
under the PRA. OMB has previously approved the information collection 
activities contained in the existing regulations (40 CFR part 63, 
subpart UUUUU) and has assigned OMB control number 2060-0567. This 
action is believed to result in no changes to the ICR of the February 
2012 final MATS rule, so that the information collection estimate of 
project cost and hour burden from the final MATS have not been revised.

C. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic 
impact on a substantial number of small entities under the RFA. This 
action will not impose any requirements on small entities. This action 
finalizes changes to MATS to correct and clarify implementation issues 
raised by stakeholders.

D. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate as described in 
UMRA, 2 U.S.C. 1531-1538, and does not significantly or uniquely affect 
small governments. This rule promulgates amendments to the February 
2012 final MATS, but the amendments are clarifications to existing rule 
language to aid in implementation. Therefore, the action imposes no 
enforceable duty on any state, local, or tribal governments or the 
private sector.

E. Executive Order 13132: Federalism

    This action does not have federalism implications. It will not have 
substantial direct effects on the states, on the relationship between 
the national government and the states, or on the distribution of power 
and responsibilities among the various levels of government.

F. Executive Order 13175: Consultation and Coordination With Indian 
Tribal Governments

    This action does not have tribal implications, as specified in 
Executive Order 13175. It will not have substantial direct effects on 
tribal governments, on the relationship between the federal government 
and Indian tribes, or on the distribution of power and responsibilities 
between the federal government and Indian tribes, as specified in 
Executive Order 13175. This action clarifies certain components of the 
February 2012 final MATS. Thus, Executive Order 13175 does not apply to 
this action.

G. Executive Order 13045: Protection of Children From Environmental 
Health Risks and Safety Risks

    The EPA interprets Executive Order 13045 as applying only to those 
regulatory actions that concern environmental health or safety risks 
that the EPA has reason to believe may disproportionately affect 
children, per the definition of ``covered regulatory action'' in 
section 2-202 of the Executive Order. This action is not subject to 
Executive Order 13045 because it does not concern an environmental 
health risk or safety risk.

H. Executive Order 13211: Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution or Use

    This action is not subject to Executive Order 13211 because it is 
not a significant regulatory action under Executive Order 12866.

I. National Technology Transfer and Advancement Act (NTTAA)

    This action does not involve technical standards from those 
contained in the February 16, 2012, final rule. Therefore, the EPA did 
not consider the use of any voluntary consensus standards. See 77 FR 
9441-9443 for the NTTAA discussion in the February 16, 2012, final 
rule.

J. Executive Order 12898: Federal Actions To Address Environmental 
Justice in Minority Populations and Low-Income Populations

    The EPA believes the human health or environmental risk addressed 
by this action will not have potential disproportionately high and 
adverse human health or environmental effects on minority, low-income, 
or indigenous populations because it does not affect the level of 
protection provided to human health or the environment.
    The environmental justice finding in the February 2012 final MATS 
remains relevant in this action, which finalizes changes to the rule to 
correct and clarify implementation issues raised by stakeholders.

K. Congressional Review Act (CRA)

    This action is subject to the CRA, and the EPA will submit a rule 
report to each House of the Congress and to the Comptroller General of 
the United States. This action is not a ``major rule'' as defined by 5 
U.S.C. 804(2).

List of Subjects

40 CFR Part 60

    Environmental protection, Administrative practice and procedure, 
Air pollution control, Intergovernmental relations, Reporting and 
recordkeeping requirements.

40 CFR Part 63

    Environmental protection, Administrative practice and procedure, 
Air pollution control, Hazardous substances, Intergovernmental 
relations, Reporting and recordkeeping requirements.


[[Page 20180]]


    Dated: March 17, 2016.
Gina McCarthy,
Administrator.
    For the reasons discussed in the preamble, the EPA amends 40 CFR 
parts 60 and 63 as follows:

PART 60--STANDARDS OF PERFORMANCE FOR NEW STATIONARY SOURCES

0
1. The authority citation for part 60 continues to read as follows:

    Authority:  42 U.S.C. 7401 et seq.


0
2. Section 60.48Da is amended by revising paragraph (f) to read as 
follows:


Sec.  60.48Da  Compliance provisions.

* * * * *
    (f) For affected facilities for which construction, modification, 
or reconstruction commenced before May 4, 2011, compliance with the 
applicable daily average PM emissions limit is determined by 
calculating the arithmetic average of all hourly emission rates each 
boiler operating day, except for data obtained during startup, 
shutdown, or malfunction periods. Daily averages are only calculated 
for boiler operating days that have non-out-of-control data for at 
least 18 hours of unit operation during which the standard applies. 
Instead, all of the non-out-of-control hourly emission rates of the 
operating day(s) not meeting the minimum 18 hours non-out-of-control 
data daily average requirement are averaged with all of the non-out-of-
control hourly emission rates of the next boiler operating day with 18 
hours or more of non-out-of-control PM CEMS data to determine 
compliance. For affected facilities for which construction or 
reconstruction commenced after May 3, 2011 that elect to demonstrate 
compliance using PM CEMS, compliance with the applicable PM emissions 
limit in Sec.  60.42Da is determined on a 30-boiler operating day 
rolling average basis by calculating the arithmetic average of all 
hourly PM emission rates for the 30 successive boiler operating days, 
except for data obtained during periods of startup and shutdown.
* * * * *

PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS 
FOR SOURCE CATEGORIES

0
3. The authority citation for part 63 continues to read as follows:

    Authority:  42 U.S.C. 7401 et seq.


0
4. Section 63.9983 is amended by:
0
a. Revising the section heading and paragraphs (a), (b), and (c); and
0
b. Adding paragraph (e).
    The revisions and addition read as follows:


Sec.  63.9983  Are any fossil fuel-fired electric generating units not 
subject to this subpart?

* * * * *
    (a) Any unit designated as a major source stationary combustion 
turbine subject to subpart YYYY of this part and any unit designated as 
an area source stationary combustion turbine, other than an integrated 
gasification combined cycle (IGCC) unit.
    (b) Any electric utility steam generating unit that is not a coal- 
or oil-fired EGU and that meets the definition of a natural gas-fired 
EGU in Sec.  63.10042.
    (c) Any electric utility steam generating unit that has the 
capability of combusting more than 25 MW of coal or oil but does not 
meet the definition of a coal- or oil-fired EGU because it did not fire 
sufficient coal or oil to satisfy the average annual heat input 
requirement set forth in the definitions for coal-fired and oil-fired 
EGUs in Sec.  63.10042. Heat input means heat derived from combustion 
of fuel in an EGU and does not include the heat derived from preheated 
combustion air, recirculated flue gases or exhaust gases from other 
sources (such as stationary gas turbines, internal combustion engines, 
and industrial boilers).
* * * * *
    (e) Any electric utility steam generating unit that meets the 
definition of a natural gas-fired EGU under this subpart and that fires 
at least 10 percent biomass is an industrial boiler subject to 
standards established under subpart DDDDD of this part, if it otherwise 
meets the applicability provisions in that rule.


0
5. Section 63.9991 is amended by revising paragraphs (c)(1) and (2) to 
read as follows:


Sec.  63.9991  What emission limitations, work practice standards, and 
operating limits must I meet?

* * * * *
    (c) * * *
    (1) Has a system using wet or dry flue gas desulfurization 
technology and an SO2 continuous emissions monitoring system 
(CEMS) installed on the EGU; and
    (2) At all times, you operate the wet or dry flue gas 
desulfurization technology and the SO2 CEMS installed on the 
EGU consistent with Sec.  63.10000(b).

0
6. Section 63.10000 is amended by revising paragraphs (a), (c)(1)(i), 
(c)(2)(iii), (f), (g), and (i)(1) and adding paragraphs (m) and (n) to 
read as follows:


Sec.  63.10000  What are my general requirements for complying with 
this subpart?

    (a) You must be in compliance with the emission limits and 
operating limits in this subpart. These limits apply to you at all 
times except during periods of startup and shutdown; however, for coal-
fired, liquid oil-fired, or solid oil-derived fuel-fired EGUs, you are 
required to meet the work practice requirements, items 3 and 4, in 
Table 3 to this subpart during periods of startup or shutdown.
* * * * *
    (c)(1) * * *
    (i) For a coal-fired or solid oil-derived fuel-fired EGU or IGCC 
EGU, you may conduct initial performance testing in accordance with 
Sec.  63.10005(h), to determine whether the EGU qualifies as a low 
emitting EGU (LEE) for one or more applicable emission limits, except 
as otherwise provided in paragraphs (c)(1)(i)(A) and (B) of this 
section:
    (A) Except as provided in paragraph (c)(1)(i)(C) of this section, 
you may not pursue the LEE option if your coal-fired, IGCC, or solid 
oil-derived fuel-fired EGU is equipped with a main stack and a bypass 
stack or bypass duct configuration that allows the effluent to bypass 
any pollutant control device.
    (B) You may not pursue the LEE option for Hg if your coal-fired, 
solid oil-derived fuel-fired EGU or IGCC EGU is new.
    (C) You may pursue the LEE option provided that:
    (1) Your EGU's control device bypass emissions are measured in the 
bypass stack or duct or your control device bypass exhaust is routed 
through the EGU main stack so that emissions are measured during the 
bypass event; or
    (2) Except for hours during which only clean fuel is combusted, you 
bypass your EGU control device only during emergency periods for no 
more than a total of 2 percent of your EGU's annual operating hours; 
you use clean fuels to the maximum extent possible during an emergency 
period; and you prepare and submit a report describing the emergency 
event, its cause, corrective action taken, and estimates of emissions 
released during the emergency event. You must include these emergency 
emissions along with performance test results in assessing whether your 
EGU maintains LEE status.
* * * * *
    (2) * * *

[[Page 20181]]

    (iii) If your existing liquid oil-fired unit does not qualify as a 
LEE for hydrogen chloride (HCl) or for hydrogen fluoride (HF), you may 
demonstrate initial and continuous compliance through use of an HCl 
CEMS, an HF CEMS, or an HCl and HF CEMS, installed and operated in 
accordance with Appendix B to this rule. As an alternative to HCl CEMS, 
HF CEMS, or HCl and HF CEMS, you may demonstrate initial and continuous 
compliance through quarterly performance testing and parametric 
monitoring for HCl and HF. If you choose to use quarterly testing and 
parametric monitoring, then you must also develop a site-specific 
monitoring plan that identifies the CMS you will use to ensure that the 
operations of the EGU remains consistent with those during the 
performance test. As another alternative, you may measure or obtain, 
and keep records of, fuel moisture content; as long as fuel moisture 
does not exceed 1.0 percent by weight, you need not conduct other HCl 
or HF monitoring or testing.
* * * * *
    (f) Except as provided under paragraph (n) of this section, you are 
subject to the requirements of this subpart for at least 6 months 
following the last date you met the definition of an EGU subject to 
this subpart (e.g., 6 months after a cogeneration unit provided more 
than one third of its potential electrical output capacity and more 
than 25 megawatts electrical output to any power distributions system 
for sale). You may opt to remain subject to the provisions of this 
subpart beyond 6 months after the last date you met the definition of 
an EGU subject to this subpart, unless your unit is a solid waste 
incineration unit subject to standards under CAA section 129 (e.g., 40 
CFR part 60, subpart CCCC (New Source Performance Standards (NSPS) for 
Commercial and Industrial Solid Waste Incineration Units, or subpart 
DDDD (Emissions Guidelines (EG) for Existing Commercial and Industrial 
Solid Waste Incineration Units). Notwithstanding the provisions of this 
subpart, an EGU that starts combusting solid waste is immediately 
subject to standards under CAA section 129 and the EGU remains subject 
to those standards until the EGU no longer meets the definition of a 
solid waste incineration unit consistent with the provisions of the 
applicable CAA section 129 standards.
    (g) Except as provided under paragraph (n) of this section, if your 
unit no longer meets the definition of an EGU subject to this subpart 
you must be in compliance with any newly applicable standards on the 
date you are no longer subject to this subpart. The date you are no 
longer subject to this subpart is a date selected by you, that must be 
at least 6 months from the date that your unit last met the definition 
of an EGU subject to this subpart or the date you begin combusting 
solid waste, consistent with Sec.  63.9983(d). Your source must remain 
in compliance with this subpart until the date you select to cease 
complying with this subpart or the date you begin combusting solid 
waste, whichever is earlier.
* * * * *
    (i)(1) If you own or operate an EGU subject to this subpart and 
cease to operate in a manner that causes your unit to meet the 
definition of an EGU subject to this subpart, you must be in compliance 
with any newly applicable section 112 or 129 standards on the date you 
selected consistent with paragraphs (g) and (n) of this section.
* * * * *
    (m) Should you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, on or before the date your 
EGU is subject to this subpart, you must install, verify, operate, 
maintain, and quality assure each monitoring system necessary for 
demonstrating compliance with the work practice standards for PM or 
non-mercury HAP metals controls during startup periods and shutdown 
periods required to comply with Sec.  63.10020(e).
    (1) You may rely on monitoring system specifications or 
instructions or manufacturer's specifications when installing, 
verifying, operating, maintaining, and quality assuring each monitoring 
system.
    (2) You must collect, record, report, and maintain data obtained 
from these monitoring systems during startup periods and shutdown 
periods.
    (n) If you have permanently converted your EGU from coal or oil to 
natural gas or biomass after your compliance date (or, if applicable, 
after your approved extended compliance date), as demonstrated by being 
subject to a permit provision or physical limitation (including 
retirement) that prevents you from operating in a manner that would 
subject you to this subpart, you are no longer subject to this subpart, 
notwithstanding the coal or oil usage in the previous calendar years. 
The date on which you are no longer subject to this subpart is the date 
on which you converted to natural gas or biomass firing; it is also the 
date on which you must be in compliance with any newly applicable 
standards.


Sec.  63.10001  [Removed and Reserved]

0
7. Section 63.10001 is removed and reserved.

0
8. Section 63.10005 is amended by:
0
a. Revising paragraphs (a) introductory text, (a)(2) introductory text, 
(a)(2)(i) and (ii), and (b)(4);
0
b. Adding paragraph (b)(6);
0
c. Revising paragraphs (d)(3), (d)(4)(i), (f), (h) introductory text, 
(h)(3) introductory text, (h)(3)(i)(D), and (h)(3)(iii) introductory 
text; and
0
d. Removing paragraphs (i)(4)(iii) and (iv).
    The revisions and additions read as follows:


Sec.  63.10005  What are my initial compliance requirements and by what 
date must I conduct them?

    (a) General requirements. For each of your affected EGUs, you must 
demonstrate initial compliance with each applicable emissions limit in 
Table 1 or 2 of this subpart through performance testing. Where two 
emissions limits are specified for a particular pollutant (e.g., a heat 
input-based limit in lb/MMBtu and a gross output-based limit in lb/
MWh), you may demonstrate compliance with either emission limit. For a 
particular compliance demonstration, you may be required to conduct one 
or more of the following activities in conjunction with performance 
testing: collection of data, e.g., hourly gross output data 
(megawatts); establishment of operating limits according to Sec.  
63.10011 and Tables 4 and 7 to this subpart; and CMS performance 
evaluations. In all cases, you must demonstrate initial compliance no 
later than the date in paragraph (f) of this section for tune-up work 
practices for existing EGUs; the date that compliance must be 
demonstrated, as given in Sec.  63.9984 for other requirements for 
existing EGUs; and in paragraph (g) of this section for all 
requirements for new EGUs.
* * * * *
    (2) To demonstrate initial compliance using either a CMS that 
measures HAP concentrations directly (i.e., an Hg, HCl, or HF CEMS, or 
a sorbent trap monitoring system) or an SO2 or PM CEMS, the 
initial performance test shall consist of 30- or, for certain coal-
fired existing EGUs that use emissions averaging for Hg, 90-boiler 
operating days. If the CMS is certified prior to the compliance date 
(or, if applicable, the approved extended compliance date), the test 
shall begin with the first operating day on or after that date, except 
as otherwise provided in paragraph (b) of this section. If the CMS is 
not certified prior to the compliance

[[Page 20182]]

date, the test shall begin with the first operating day after 
certification testing is successfully completed. In all cases, the 
initial 30- or 90- operating day averaging period must be completed on 
or before the date that compliance must be demonstrated (i.e., 180 days 
after the applicable compliance date).
    (i) The CMS performance test must demonstrate compliance with the 
applicable Hg, HCl, HF, PM, or SO2 emissions limit in Table 
1 or 2 to this subpart.
    (ii) You must collect hourly data from auxiliary monitoring systems 
(i.e., stack gas flow rate, CO2, O2, or moisture, 
as applicable) during the performance test period, in order to convert 
the pollutant concentrations to units of the standard. If you choose to 
comply with a gross output-based emission limit, you must also collect 
hourly gross output data during the performance test period.
* * * * *
    (b) * * *
    (4) A record of all parameters needed to convert pollutant 
concentrations to units of the emission standard (e.g., stack flow 
rate, diluent gas concentrations, hourly gross outputs) is available 
for the entire performance test period; and
* * * * *
    (6) For performance stack test data that are collected prior to the 
date that compliance must be demonstrated and are used to demonstrate 
initial compliance with applicable emissions limits, the interval for 
subsequent stack tests begins on the date that compliance must be 
demonstrated.
* * * * *
    (d) * * *
    (3) For affected EGUs that are either required to or elect to 
demonstrate initial compliance with the applicable Hg emission limit in 
Table 1 or 2 of this subpart using Hg CEMS or sorbent trap monitoring 
systems, initial compliance must be demonstrated no later than the 
applicable date specified in Sec.  63.9984(f) for existing EGUs and in 
paragraph (g) of this section for new EGUs. Initial compliance is 
achieved if the arithmetic average of 30- (or 90-) boiler operating 
days of quality-assured CEMS (or sorbent trap monitoring system) data, 
expressed in units of the standard (see section 6.2 of appendix A to 
this subpart), meets the applicable Hg emission limit in Table 1 or 2 
to this subpart.
    (4) * * *
    (i) You must demonstrate initial compliance no later than the 
applicable date specified in Sec.  63.9984(f) for existing EGUs and in 
paragraph (g) of this section for new EGUs.
* * * * *
    (f) For an existing EGU without a neural network, a tune-up, 
following the procedures in Sec.  63.10021(e), must occur within 6 
months (180 days) after April 16, 2015. For an existing EGU with a 
neural network, a tune-up must occur within 18 months (545 days) after 
April 16, 2016. If a tune-up occurs prior to April 16, 2015, you must 
keep records showing that the tune-up met all rule requirements.
* * * * *
    (h) Low emitting EGUs. The provisions of this paragraph (h) apply 
to pollutants with emissions limits from new EGUs except Hg and to all 
pollutants with emissions limits from existing EGUs. You may pursue 
this compliance option unless prohibited pursuant to Sec.  
63.10000(c)(1)(i).
* * * * *
    (3) For Hg, you must conduct a 30- (or 90-) boiler operating day 
performance test using Method 30B in appendix A-8 to part 60 of this 
chapter to determine whether a unit qualifies for LEE status. Locate 
the Method 30B sampling probe tip at a point within 10 percent of the 
duct area centered about the duct's centroid at a location that meets 
Method 1 in appendix A-1 to part 60 of this chapter and conduct at 
least three nominally equal length test runs over the 30- (or 90-) 
boiler operating day test period. You may use a pair of sorbent traps 
to sample the stack gas for a period consistent with that given in 
section 5.2.1 of appendix A to this subpart. Collect Hg emissions data 
continuously over the entire test period (except when changing sorbent 
traps or performing required reference method QA procedures). As an 
alternative to constant rate sampling per Method 30B, you may use 
proportional sampling per section 8.2.2 of Performance Specification 12 
B in appendix B to part 60 of this chapter.
    (i) * * *
    (D) Hourly gross output data (megawatts), from facility records.
* * * * *
    (iii) Calculate the average Hg concentration, in [micro]g/m\3\ (dry 
basis), for the 30- (or 90-) boiler operating day performance test, as 
the arithmetic average of all Method 30B sorbent trap results. Also 
calculate, as applicable, the average values of CO2 or 
O2 concentration, stack gas flow rate, stack gas moisture 
content, and gross output for the test period. Then:
* * * * *

0
9. Section 63.10006 is amended by revising paragraph (f) and removing 
paragraph (j) to read as follows:


Sec.  63.10006  When must I conduct subsequent performance tests or 
tune-ups?

* * * * *
    (f) Time between performance tests. (1) Notwithstanding the 
provisions of Sec.  63.10021(d)(1), the requirements listed in 
paragraphs (g) and (h) of this section, and the requirements of 
paragraph (f)(3) of this section, you must complete performance tests 
for your EGU as follows:
    (i) At least 45 calendar days, measured from the test's end date, 
must separate performance tests conducted every quarter;
    (ii) For annual testing:
    (A) At least 320 calendar days, measured from the test's end date, 
must separate performance tests;
    (B) At least 320 calendar days, measured from the test's end date, 
must separate annual sorbent trap mercury testing for 30-boiler 
operating day LEE tests;
    (C) At least 230 calendar days, measured from the test's end date, 
must separate annual sorbent trap mercury testing for 90-boiler 
operating day LEE tests; and
    (iii) At least 1,050 calendar days, measured from the test's end 
date, must separate performance tests conducted every 3 years.
    (2) For units demonstrating compliance through quarterly emission 
testing, you must conduct a performance test in the 4th quarter of a 
calendar year if your EGU has skipped performance tests in the first 3 
quarters of the calendar year.
    (3) If your EGU misses a performance test deadline due to being 
inoperative and if 168 or more boiler operating hours occur in the next 
test period, you must complete an additional performance test in that 
period as follows:
    (i) At least 15 calendar days must separate two performance tests 
conducted in the same quarter.
    (ii) At least 107 calendar days must separate two performance tests 
conducted in the same calendar year.
    (iii) At least 350 calendar days must separate two performance 
tests conducted in the same 3 year period.
* * * * *

0
10. Section 63.10007 is amended by revising paragraph (f)(2) to read as 
follows:


Sec.  63.10007  What methods and other procedures must I use for the 
performance tests?

* * * * *

[[Page 20183]]

    (f) * * *
    (2) Default gross output. If you use CEMS to continuously monitor 
Hg, HCl, HF, SO2, or PM emissions (or, if applicable, 
sorbent trap monitoring systems to continuously collect Hg emissions 
data), the following default value is available for use in the emission 
rate calculations during startup periods or shutdown periods (as 
defined in Sec.  63.10042). For the purposes of this subpart, this 
default value is not considered to be substitute data. For a startup or 
shutdown hour in which there is heat input to an affected EGU but zero 
gross output, you must calculate the pollutant emission rate using a 
value equivalent to 5% of the maximum sustainable gross output, 
expressed in megawatts, as defined in section 6.5.2.1(a)(1) of appendix 
A to part 75 of this chapter. This default gross output is either the 
nameplate capacity of the EGU or the highest gross output observed in 
at least four representative quarters of EGU operation. For a monitored 
common stack, the default gross output is used only when all EGUs are 
operating (i.e., combusting fuel) are in startup or shutdown mode, and 
have zero electrical generation. Under those conditions, a default 
gross output equal to 5% of the combined maximum sustainable gross 
output of the EGUs that are operating but have a total of zero gross 
output must be used to calculate the hourly gross output-based 
pollutant emissions rate.
* * * * *

0
11. Section 63.10009 is amended by revising paragraphs (a)(2) 
introductory text, (a)(2)(i), (b)(1) through (3), (e), (f) introductory 
text, (f)(2), (g), (j)(1)(ii), and (j)(2) introductory text to read as 
follows:


Sec.  63.10009  May I use emissions averaging to comply with this 
subpart?

    (a) * * *
    (2) You may demonstrate compliance by emissions averaging among the 
existing EGUs in the same subcategory, if your averaged Hg emissions 
for EGUs in the ``unit designed for coal >=8,300 Btu/lb'' subcategory 
are equal to or less than 1.2 lb/TBtu or 1.3E-2 lb/GWh on a 30-boiler 
operating day basis or if your averaged emissions of individual, other 
pollutants from other subcategories of such EGUs are equal to or less 
than the applicable emissions limit in Table 2 to this subpart, 
according to the procedures in this section. Note that except for the 
alternate Hg emissions limit from EGUs in the ``unit designed for coal 
>= 8,300 Btu/lb'' subcategory, the averaging time for emissions 
averaging for pollutants is 30 days (rolling daily) using data from 
CEMS or a combination of data from CEMS and manual performance (LEE) 
testing. The averaging time for emissions averaging for the alternate 
Hg limit (equal to or less than 1.0 lb/TBtu or 1.1E-2 lb/GWh) from EGUs 
in the ``unit designed for coal >= 8,300 Btu/lb'' subcategory is 90-
boiler operating days (rolling daily) using data from CEMS, sorbent 
trap monitoring, or a combination of monitoring data and data from 
manual performance (LEE) testing. For the purposes of this paragraph, 
30- (or 90-) group boiler operating days is defined as a period during 
which at least one unit in the emissions averaging group operates on 
each of the 30 or 90 days. You must calculate the weighted average 
emissions rate for the group in accordance with the procedures in this 
paragraph using the data from all units in the group including any that 
operate fewer than 30 (or 90) days during the preceding 30 (or 90) 
group boiler days.
    (i) You may choose to have your EGU emissions averaging group meet 
either the heat input basis (MMBtu or TBtu, as appropriate for the 
pollutant) or gross output basis (MWh or GWh, as appropriate for the 
pollutant).
* * * * *
    (b) * * *
    (1) Group eligibility equations.
    [GRAPHIC] [TIFF OMITTED] TR06AP16.001
    
Where:

WAERm = Maximum Weighted Average Emission Rate in terms 
of lb/heat input or lb/gross output,
Hermi,j = hourly emission rate (e.g., lb/
MMBtu, lb/MWh) from CEMS or sorbent trap monitoring as determined 
during the initial compliance determination from EGU j,
Rmmj = Maximum rated heat input, MMBtu/h, or maximum 
rated gross output, MWh/h, for EGU j,
p = number of EGUs in emissions averaging group that rely on CEMS,
Terk = Emissions rate (lb/MMBTU or lb/MWh) as determined 
during the initial compliance determination of EGU k,
Rmtk = Maximum rated heat input, MMBtu/h, or maximum 
rated gross output, MWh/h, for EGU k, and
m = number of EGUs in emissions averaging group that rely on 
emissions testing.
[GRAPHIC] [TIFF OMITTED] TR06AP16.002

Where:

    Variables with the similar names share the descriptions for 
Equation 1a of this section,
Smmj = maximum steam generation, lbsteam/h or 
lb/gross output, for EGU j,
Cfmj = conversion factor, calculated from the most recent 
compliance test results, in terms units of heat output or gross 
output per pound of steam generated (MMBtu/lbsteam or 
MWh/lbsteam) from EGU j,
Smtk = maximum steam generation, lbsteam/h or 
lb/gross output, for EGU k, and
Cfmk = conversion factor, calculated from the most recent 
compliance test results, in terms units of heat output or gross 
output per pound of steam generated (MMBtu/lbsteam or 
MWh/lbsteam) from EGU k.
    (2) Weighted 30-boiler operating day rolling average emissions 
rate equations for pollutants other than Hg. Use Equation 2a or 2b 
of this section to calculate the 30 day rolling average emissions 
daily.

[[Page 20184]]

[GRAPHIC] [TIFF OMITTED] TR06AP16.003

Where:

Heri = hourly emission rate (e.g., lb/MMBtu, lb/MWh) from 
unit i's CEMS for the preceding 30-group boiler operating days,
Rmi = hourly heat input or gross output from unit i for 
the preceding 30-group boiler operating days,
p = number of EGUs in emissions averaging group that rely on CEMS or 
sorbent trap monitoring,
n = number of hours that hourly rates are collected over 30-group 
boiler operating days,
Teri = Emissions rate from most recent emissions test of 
unit i in terms of lb/heat input or lb/gross output,
Rti = Total heat input or gross output of unit i for the 
preceding 30-boiler operating days, and
m = number of EGUs in emissions averaging group that rely on 
emissions testing.

[GRAPHIC] [TIFF OMITTED] TR06AP16.004

Where:

variables with similar names share the descriptions for Equation 2a 
of this section,
Smi = steam generation in units of pounds from unit i 
that uses CEMS for the preceding 30-group boiler operating days,
Cfmi = conversion factor, calculated from the most recent 
compliance test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses CEMS from the preceding 30 group boiler operating days,
Sti = steam generation in units of pounds from unit i 
that uses emissions testing, and
Cfti = conversion factor, calculated from the most recent 
compliance test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses emissions testing.

    (3) Weighted 90-boiler operating day rolling average emissions 
rate equations for Hg emissions from EGUs in the ``coal-fired unit 
not low rank virgin coal'' subcategory. Use Equation 3a or 3b of 
this section to calculate the 90-day rolling average emissions 
daily.

[GRAPHIC] [TIFF OMITTED] TR06AP16.005

Where:

Heri = hourly emission rate from unit i's CEMS or Hg 
sorbent trap monitoring system for the preceding 90-group boiler 
operating days,
Rmi = hourly heat input or gross output from unit i for 
the preceding 90-group boiler operating days,
p = number of EGUs in emissions averaging group that rely on CEMS,
n = number of hours that hourly rates are collected over the 90-
group boiler operating days,
Teri = Emissions rate from most recent emissions test of 
unit i in terms of lb/heat input or lb/gross output,
Rti = Total heat input or gross output of unit i for the 
preceding 90-boiler operating days, and
m = number of EGUs in emissions averaging group that rely on 
emissions testing.

[GRAPHIC] [TIFF OMITTED] TR06AP16.006

Where:

variables with similar names share the descriptions for Equation 2a 
of this section,
Smi = steam generation in units of pounds from unit i 
that uses CEMS or a Hg sorbent trap monitoring for the preceding 90-
group boiler operating days,
Cfmi = conversion factor, calculated from the most recent 
compliance test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses CEMS or sorbent trap monitoring from the preceding 90-
group boiler operating days,
Sti = steam generation in units of pounds from unit i 
that uses emissions testing, and
Cfti = conversion factor, calculated from the most recent 
emissions test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses emissions testing.
* * * * *
    (e) The weighted-average emissions rate from the existing EGUs 
participating in the emissions averaging option must be in compliance 
with the limits in Table 2 to this subpart at all times following the 
date that you begin emissions averaging.
    (f) Emissions averaging group eligibility demonstration. You must 
demonstrate the ability for the EGUs included in the emissions 
averaging group to demonstrate initial compliance according to 
paragraph (f)(1) or (2) of this section using the maximum rated heat 
input or gross output over a 30- (or 90-) boiler operating day period 
of each EGU and the results of the initial performance tests. For this 
demonstration and prior to preparing your emissions averaging plan, you 
must conduct required emissions monitoring for 30- (or 90-) days of 
boiler operation and any required manual performance testing to 
calculate maximum weighted average emissions rate in accordance with 
this section. If, before the start of your initial compliance 
demonstration, the Administrator becomes aware that you intend to use 
emissions averaging for that demonstration, or if your initial 
Notification of Compliance Status (NOCS) indicates that you intend to

[[Page 20185]]

implement emissions averaging at a future date, the Administrator may 
require you to submit your proposed emissions averaging plan and 
supporting data for approval. If the Administrator requires approval of 
your plan, you may not begin using emissions averaging until the 
Administrator approves your plan.
* * * * *
    (2) If you are not capable of monitoring heat input or gross 
output, and the EGU generates steam for purposes other than generating 
electricity, you may use Equation 1b of paragraph (b) of this section 
as an alternative to using Equation 1a of paragraph (b) of this section 
to demonstrate that the maximum weighted average emissions rates of 
filterable PM, HF, SO2, HCl, non-Hg HAP metals, or Hg 
emissions from the existing units participating in the emissions 
averaging group do not exceed the emission limits in Table 2 to this 
subpart.
    (g) You must determine the weighted average emissions rate in units 
of the applicable emissions limit on a 30 group boiler operating day 
rolling average basis (or, if applicable, on a 90 group boiler 
operating day rolling average basis for Hg) according to paragraphs 
(g)(1) and (2) of this section. The first averaging period ends on the 
30th (or, if applicable, 90th for the alternate Hg emission limit) 
group boiler operating day after the date that you begin emissions 
averaging.
    (1) You must use Equation 2a or 3a of paragraph (b) of this section 
to calculate the weighted average emissions rate using the actual heat 
input or gross output for each existing unit participating in the 
emissions averaging option.
    (2) If you are not capable of monitoring heat input or gross 
output, you may use Equation 2b or 3b of paragraph (b) of this section 
as an alternative to using Equation 2a of paragraph (b) of this section 
to calculate the average weighted emission rate using the actual steam 
generation from the units participating in the emissions averaging 
option.
* * * * *
    (j) * * *
    (1) * * *
    (ii) The process weighting parameter (heat input, gross output, or 
steam generated) that will be monitored for each averaging group;
* * * * *
    (2) If, as described in paragraph (f) of this section, the 
Administrator requests you to submit the averaging plan for review and 
approval, you must receive approval before initiating emissions 
averaging.
* * * * *

0
12. Section 63.10010 is amended by revising paragraphs (a)(4), (f)(3) 
and (4), (h)(6)(i) and (ii), (i)(5)(i)(A) and (B), (j)(1)(i), 
(j)(4)(i)(A) and (B), and (l) to read as follows:


Sec.  63.10010  What are my monitoring, installation, operation, and 
maintenance requirements?

    (a) * * *
    (4) Unit with a main stack and a bypass stack that exhausts to the 
atmosphere independent of the main stack. If the exhaust configuration 
of an affected unit consists of a main stack and a bypass stack, you 
shall install CEMS on both the main stack and the bypass stack. If it 
is not feasible to certify and quality-assure the data from a 
monitoring system on the bypass stack, you shall:
    (i) Route the exhaust from the bypass through the main stack and 
its monitoring so that bypass emissions are measured; or
    (ii) Install a CEMS only on the main stack and count hours that the 
bypass stack is in use as hours of deviation from the monitoring 
requirements.
* * * * *
    (f) * * *
    (3) Calculate and record a 30-boiler operating day rolling average 
SO2 emission rate in the units of the standard, updated 
after each new boiler operating day. Each 30-boiler operating day 
rolling average emission rate is the average of all of the valid hourly 
SO2 emission rates in the 30 boiler operating day period.
    (4) Use only unadjusted, quality-assured SO2 
concentration values in the emissions calculations; do not apply bias 
adjustment factors to the part 75 SO2 data and do not use 
part 75 substitute data values. For startup or shutdown hours (as 
defined in Sec.  63.10042) the default gross output and the diluent cap 
are available for use in the hourly SO2 emission rate 
calculations, as described in Sec.  63.10007(f). Use a flag to identify 
each startup or shutdown hour and report a special code if the diluent 
cap or default gross output is used to calculate the SO2 
emission rate for any of these hours.
* * * * *
    (h) * * *
    (6) * * *
    (i) Any data collected during periods of monitoring system 
malfunctions, repairs associated with monitoring system malfunctions, 
or required monitoring system quality assurance or quality control 
activities that temporarily interrupt the measurement of output data 
from the PM CPMS. You must report any monitoring system malfunctions or 
out of control periods in your annual deviation reports. You must 
report any monitoring system quality assurance or quality control 
activities per the requirements of Sec.  63.10031(b);
    (ii) Any data collected during periods when the monitoring system 
is out of control as specified in your site-specific monitoring plan, 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any such periods in your annual deviation report;
* * * * *
    (i) * * *
    (5) * * *
    (i) * * *
    (A) Any data collected during periods of monitoring system 
malfunctions, repairs associated with monitoring system malfunctions, 
or required monitoring system quality assurance or quality control 
activities that temporarily interrupt the measurement of emissions 
(e.g., calibrations, certain audits). You must report any monitoring 
system malfunctions or out of control periods in your annual deviation 
reports. You must report any monitoring system quality assurance or 
quality control activities per the requirements of Sec.  63.10031(b);
    (B) Any data collected during periods when the monitoring system is 
out of control as specified in your site-specific monitoring plan, 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any such periods in your annual deviation report;
* * * * *
    (j) * * *
    (1)(i) Install, calibrate, operate, and maintain your HAP metals 
CEMS according to your CMS quality control program, as described in 
Sec.  63.8(d)(2). The reportable measurement output from the HAP metals 
CEMS must be expressed in units of the applicable emissions limit 
(e.g., lb/MMBtu, lb/MWh) and in the form of a 30-boiler operating day 
rolling average.
* * * * *
    (4) * * *
    (i) * * *
    (A) Any data collected during periods of monitoring system 
malfunctions, repairs associated with monitoring

[[Page 20186]]

system malfunctions, or required monitoring system quality assurance or 
quality control activities that temporarily interrupt the measurement 
of emissions (e.g., calibrations, certain audits). You must report any 
monitoring system malfunctions or out of control periods in your annual 
deviation reports. You must report any monitoring system quality 
assurance or quality control activities per the requirements of Sec.  
63.10031(b);
    (B) Any data collected during periods when the monitoring system is 
out of control as specified in your site-specific monitoring plan, 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any monitoring system malfunctions or out of control periods in 
your annual deviation reports. You must report any monitoring system 
quality assurance or quality control activities per the requirements of 
Sec.  63.10031(b);
* * * * *
    (l) Should you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, you must install, verify, 
operate, maintain, and quality assure each monitoring system necessary 
for demonstrating compliance with the PM or non-mercury metals work 
practice standards required to comply with Sec.  63.10020(e).
    (1) You shall develop a site-specific monitoring plan for PM or 
non-mercury metals work practice monitoring during startup periods.
    (2) You shall submit the site-specific monitoring plan upon request 
by the Administrator.
    (3) The provisions of the monitoring plan must address the 
following items:
    (i) Monitoring system installation;
    (ii) Performance and equipment specifications;
    (iii) Schedule for initial and periodic performance evaluations;
    (iv) Performance evaluation procedures and acceptance criteria;
    (v) On-going operation and maintenance procedures; and
    (vi) On-going recordkeeping and reporting procedures.
    (4) You may rely on monitoring system specifications or 
instructions or manufacturer's specifications to address paragraphs 
(l)(3)(i) through (vi) of this section.
    (5) You must operate and maintain the monitoring system according 
to the site-specific monitoring plan.

0
13. Section 63.10011 is amended by revising paragraphs (b), (c), (e), 
and (g) to read as follows:


Sec.  63.10011  How do I demonstrate initial compliance with the 
emissions limits and work practice standards?

* * * * *
    (b) If you are subject to an operating limit in Table 4 to this 
subpart, you demonstrate initial compliance with HAP metals or 
filterable PM emission limit(s) through performance stack tests and you 
elect to use a PM CPMS to demonstrate continuous performance, or if, 
for a liquid oil-fired EGU, and you use quarterly stack testing for HCl 
and HF plus site-specific parameter monitoring to demonstrate 
continuous performance, you must also establish a site-specific 
operating limit, in accordance with Sec.  63.10007 and Table 6 to this 
subpart. You may use only the parametric data recorded during 
successful performance tests (i.e., tests that demonstrate compliance 
with the applicable emissions limits) to establish an operating limit.
    (c)(1) If you use CEMS or sorbent trap monitoring systems to 
measure a HAP (e.g., Hg or HCl) directly, the initial performance test, 
shall consist of a 30-boiler operating day (or, for certain coal-fired, 
existing EGUs that use emissions averaging for Hg, a 90-boiler 
operating day) rolling average emissions rate obtained with a certified 
CEMS or sorbent trap system, expressed in units of the standard. If the 
monitoring system is certified prior to the applicable compliance date, 
the initial averaging period shall either begin with: The first boiler 
operating day on or after the compliance date; or 30 (or, if 
applicable, 90) boiler operating days prior to that date, as described 
in Sec.  63.10005(b). In all cases, the initial 30- or 90-boiler 
operating day averaging period must be completed on or before the date 
that compliance must be demonstrated, in accordance with Sec.  
63.9984(f). Initial compliance is demonstrated if the results of the 
performance test meet the applicable emission limit in Table 1 or 2 to 
this subpart.
    (2) For an EGU that uses a CEMS to measure SO2 or PM 
emissions for initial compliance, the initial performance test shall 
consist of a 30-boiler operating day average emission rate obtained 
with certified CEMS, expressed in units of the standard. If the 
monitoring system is certified prior to the applicable compliance date, 
the initial averaging period shall either begin with: The first boiler 
operating day on or after the compliance date; or 30 boiler operating 
days prior to that date, as described in Sec.  63.10005(b). In all 
cases, the initial 30- boiler operating day averaging period must be 
completed on or before the date that compliance must be demonstrated, 
in accordance with Sec.  63.9984(f). Initial compliance is demonstrated 
if the results of the performance test meet the applicable 
SO2 or PM emission limit in Table 1 or 2 to this subpart.
* * * * *
    (e) You must submit a Notification of Compliance Status containing 
the results of the initial compliance demonstration, in accordance with 
Sec.  63.10030(e).
* * * * *
    (g) You must follow the startup or shutdown requirements as 
established in Table 3 to this subpart for each coal-fired, liquid oil-
fired, or solid oil-derived fuel-fired EGU.
    (1) You may use the diluent cap and default gross output values, as 
described in Sec.  63.10007(f), during startup periods or shutdown 
periods.
    (2) You must operate all CMS, collect data, calculate pollutant 
emission rates, and record data during startup periods or shutdown 
periods.
    (3) You must report the information as required in Sec.  63.10031.
    (4) If you choose to use paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 and you find that you are unable to 
safely engage and operate your particulate matter (PM) control(s) 
within 1 hour of first firing of coal, residual oil, or solid oil-
derived fuel, you may choose to rely on paragraph (1) of definition of 
``startup'' in Sec.  63.10042 or you may submit a request to use an 
alternative non-opacity emissions standard, as described below.
    (i) As mentioned in Sec.  63.6(g)(1), your request will be 
published in the Federal Register for notice and comment rulemaking. 
Until promulgation in the Federal Register of the final alternative 
non-opacity emission standard, you shall comply with paragraph (1) of 
the definition of ``startup'' in Sec.  63.10042. You shall not 
implement the alternative non-opacity emissions standard until 
promulgation in the Federal Register of the final alternative non-
opacity emission standard.
    (ii) Your request need not address the items contained in Sec.  
63.6(g)(2).
    (iii) Your request shall provide evidence of a documented 
manufacturer-identified safety issue.
    (iv) Your request shall provide information to document that the PM 
control device is adequately designed and sized to meet the PM emission 
limit applicable to the EGU.
    (v) In addition, your request shall contain documentation that:
    (A) Your EGU is using clean fuels to the maximum extent possible, 
taking into account considerations such as not compromising boiler or 
control device integrity, to bring your EGU and PM

[[Page 20187]]

control device up to the temperature necessary to alleviate or prevent 
the identified safety issues prior to the combustion of primary fuel in 
your EGU;
    (B) You have followed explicitly your EGU manufacturer's procedures 
to alleviate or prevent the identified safety issue; and
    (C) You have identified with specificity the details of your EGU 
manufacturer's statement of concern.
    (vi) Your request shall specify the other work practice standards 
you will take to limit HAP emissions during startup periods and 
shutdown periods to ensure a control level consistent with the work 
practice standards of the final rule.
    (vii) You must comply with all other work practice requirements, 
including but not limited to data collection, recordkeeping, and 
reporting requirements.

0
14. Section 63.10020 is amended by revising paragraph (e) to read as 
follows:


Sec.  63.10020  How do I monitor and collect data to demonstrate 
continuous compliance?

* * * * *
    (e) Additional requirements during startup periods or shutdown 
periods if you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU.
    (1) During each period of startup, you must record for each EGU:
    (i) The date and time that clean fuels being combusted for the 
purpose of startup begins;
    (ii) The quantity and heat input of clean fuel for each hour of 
startup;
    (iii) The gross output for each hour of startup;
    (iv) The date and time that non-clean fuel combustion begins; and
    (v) The date and time that clean fuels being combusted for the 
purpose of startup ends.
    (2) During each period of shutdown, you must record for each EGU:
    (i) The date and time that clean fuels being combusted for the 
purpose of shutdown begins;
    (ii) The quantity and heat input of clean fuel for each hour of 
shutdown;
    (iii) The gross output for each hour of shutdown;
    (iv) The date and time that non-clean fuel combustion ends; and
    (v) The date and time that clean fuels being combusted for the 
purpose of shutdown ends.
    (3) For PM or non-mercury HAP metals work practice monitoring 
during startup periods, you must monitor and collect data according to 
this section and the site-specific monitoring plan required by Sec.  
63.10010(l).
    (i) Except for an EGU that uses PM CEMS or PM CPMS to demonstrate 
compliance with the PM emissions limit, or that has LEE status for 
filterable PM or total non-Hg HAP metals for non- liquid oil-fired EGUs 
(or HAP metals emissions for liquid oil-fired EGUs), or individual non-
mercury metals CEMS, you must:
    (A) Record temperature and combustion air flow or calculated flow 
as determined from combustion equations of post-combustion (exhaust) 
gas, as well as amperage of forced draft fan(s), upstream of the 
filterable PM control devices during each hour of startup.
    (B) Record temperature and flow of exhaust gas, as well as amperage 
of any induced draft fan(s), downstream of the filterable PM control 
devices during each hour of startup.
    (C) For an EGU with an electrostatic precipitator, record the 
number of fields in service, as well as each field's secondary voltage 
and secondary current during each hour of startup.
    (D) For an EGU with a fabric filter, record the number of 
compartments in service, as well as the differential pressure across 
the baghouse during each hour of startup.
    (E) For an EGU with a wet scrubber needed for filterable PM 
control, record the scrubber liquid to flue gas ratio and the pressure 
drop across the scrubber during each hour of startup.
    (ii) [Reserved]

0
15. Section 63.10021 is amended by revising paragraphs (d)(3), (e) 
introductory text, (e)(9), and (h)(1) to read as follows:


Sec.  63.10021  How do I demonstrate continuous compliance with the 
emission limitations, operating limits, and work practice standards?

* * * * *
    (d) * * *
    (3) Must conduct site-specific monitoring using CMS to demonstrate 
compliance with the site-specific monitoring requirements in Table 7 to 
this subpart pertaining to HCl and HF emissions from a liquid oil-fired 
EGU to ensure compliance with the HCl and HF emission limits in Tables 
1 and 2 to this subpart, in accordance with the requirements of Sec.  
63.10000(c)(2)(iii). The monitoring must meet the general operating 
requirements provided in Sec.  63.10020.
    (e) Conduct periodic performance tune-ups of your EGU(s), as 
specified in paragraphs (e)(1) through (9) of this section. For your 
first tune-up, you may perform the burner inspection any time prior to 
the tune-up or you may delay the first burner inspection until the next 
scheduled EGU outage provided you meet the requirements of Sec.  
63.10005. Subsequently, you must perform an inspection of the burner at 
least once every 36 calendar months unless your EGU employs neural 
network combustion optimization during normal operations in which case 
you must perform an inspection of the burner and combustion controls at 
least once every 48 calendar months. If your EGU is offline when a 
deadline to perform the tune-up passes, you shall perform the tune-up 
work practice requirements within 30 days after the re-start of the 
affected unit.
* * * * *
    (9) Report the dates of the initial and subsequent tune-ups in hard 
copy, as specified in Sec.  63.10031(f)(5), until April 16, 2017. After 
April 16, 2017, report the date of all tune-ups electronically, in 
accordance with Sec.  63.10031(f). The tune-up report date is the date 
when tune-up requirements in paragraphs (e)(6) and (7) of this section 
are completed.
* * * * *
    (h) * * *
    (1) You may use the diluent cap and default gross output values, as 
described in Sec.  63.10007(f), during startup periods or shutdown 
periods.
* * * * *

0
16. Section 63.10023 is amended by removing and reserving paragraph 
(b)(1) and revising paragraph (b)(2) introductory text to read as 
follows:


Sec.  63.10023  How do I establish my PM CPMS operating limit and 
determine compliance with it?

* * * * *
    (b) * * *
    (2) Determine your operating limit as follows:
* * * * *

0
17. Section 63.10030 is amended by:
0
a. Revising paragraphs (e)(1) and (e)(7)(i);
0
b. Adding paragraph (e)(7)(iii);
0
c. Revising paragraph (e)(8); and
0
d. Adding paragraph (f).
    The revisions and additions read as follows:


Sec.  63.10030  What notifications must I submit and when?

* * * * *
    (e) * * *
    (1) A description of the affected source(s), including 
identification of the subcategory of the source, the design capacity of 
the source, a description of the add-on controls used on the source, 
description of the fuel(s) burned, including whether the fuel(s) were 
determined by you or EPA through a

[[Page 20188]]

petition process to be a non-waste under 40 CFR 241.3, whether the 
fuel(s) were processed from discarded non-hazardous secondary materials 
within the meaning of 40 CFR 241.3, and justification for the selection 
of fuel(s) burned during the performance test.
* * * * *
    (7) * * *
    (i) A summary of the results of the annual performance tests and 
documentation of any operating limits that were reestablished during 
this test, if applicable. If you are conducting stack tests once every 
3 years consistent with Sec.  63.10005(h)(1)(i), the date of each stack 
test conducted during the previous 3 years, a comparison of emission 
level you achieved in each stack test conducted during the previous 3 
years to the 50 percent emission limit threshold required in Sec.  
63.10006(i), and a statement as to whether there have been any 
operational changes since the last stack test that could increase 
emissions.
* * * * *
    (iii) For each of your existing EGUs, identification of each 
emissions limit as specified in Table 2 to this subpart with which you 
plan to comply.
    (A) You may switch from a mass per heat input to a mass per gross 
output limit (or vice-versa), provided that:
    (1) You submit a request that identifies for each EGU or EGU 
emissions averaging group involved in the proposed switch both the 
current and proposed emission limit;
    (2) Your request arrives to the Administrator at least 30 calendar 
days prior to the date that the switch is proposed to occur;
    (3) Your request demonstrates through performance stack test 
results completed within 30 days prior to your submission, compliance 
for each EGU or EGU emissions averaging group with both the mass per 
heat input and mass per gross output limits;
    (4) You revise and submit all other applicable plans, e.g., 
monitoring and emissions averaging, with your request; and
    (5) You maintain records of all information regarding your choice 
of emission limits.
    (B) You begin to use the revised emission limits starting in the 
next reporting period, after receipt of written acknowledgement from 
the Administrator of the switch.
    (C) From submission of your request until start of the next 
reporting period after receipt of written acknowledgement from the 
Administrator of the switch, you demonstrate compliance with both the 
mass per heat input and mass per gross output emission limits for each 
pollutant for each EGU or EGU emissions averaging group.
    (8) Identification of whether you plan to rely on paragraph (1) or 
(2) of the definition of ``startup'' in Sec.  63.10042.
    (i) Should you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, you shall include a report 
that identifies:
    (A) The original EGU installation date;
    (B) The original EGU design characteristics, including, but not 
limited to, fuel mix and PM controls;
    (C) Each design PM control device efficiency established during 
performance testing or while operating in periods other than startup 
and shutdown periods;
    (D) The design PM emission rate from the EGU in terms of pounds PM 
per MMBtu and pounds PM per hour established during performance testing 
or while operating in periods other than startup and shutdown periods;
    (E) The design time from start of fuel combustion to necessary 
conditions for each PM control device startup;
    (F) Each design PM control device efficiency upon startup of the PM 
control device, if different from the efficiency provided in paragraph 
(e)(8)(i)(C) of this section;
    (G) Current EGU PM producing characteristics, including, but not 
limited to, fuel mix and PM controls, if different from the 
characteristics provided in paragraph (e)(8)(i)(B) of this section;
    (H) Current PM control device efficiency from each PM control 
device, if different from the efficiency provided in paragraph 
(e)(8)(i)(C) of this section;
    (I) Current PM emission rate from the EGU in terms of pounds PM per 
MMBtu and pounds per hour, if different from the rate provided in 
paragraph (e)(8)(i)(D) of this section;
    (J) Current time from start of fuel combustion to conditions 
necessary for each PM control device startup, if different from the 
time provided in paragraph (e)(8)(i)(E) of this section; and
    (K) Current PM control device efficiency upon startup of each PM 
control device, if different from the efficiency provided in paragraph 
(e)(8)(i)(H) of this section.
    (ii) The report shall be prepared, signed, and sealed by a 
professional engineer licensed in the state where your EGU is located.
    (iii) You may switch from paragraph (1) of the definition of 
``startup'' in Sec.  63.10042 to paragraph (2) of the definition of 
``startup'' (or vice-versa), provided that:
    (A) You submit a request that identifies for each EGU or EGU 
emissions averaging group involved in the proposed switch both the 
current definition of ``startup'' relied on and the proposed definition 
you plan to rely on;
    (B) Your request arrives to the Administrator at least 30 calendar 
days prior to the date that the switch is proposed to occur;
    (C) You revise and submit all other applicable plans, e.g., 
monitoring and emissions averaging, with your submission;
    (D) You maintain records of all information regarding your choice 
of the definition of ``startup''; and
    (E) You begin to use the revised definition of ``startup'' in the 
next reporting period after receipt of written acknowledgement from the 
Administrator of the switch.
    (f) You must submit the notifications in Sec.  63.10000(h)(2) and 
(i)(2) that may apply to you by the dates specified.

0
18. Section 63.10031 is amended by revising paragraphs (c) introductory 
text and (c)(4) and (5) and adding paragraphs (c)(6), (7), (8), and (9) 
to read as follows:


Sec.  63.10031  What reports must I submit and when?

* * * * *
    (c) The compliance report must contain the information required in 
paragraphs (c)(1) through (9) of this section.
* * * * *
    (4) Include the date of the most recent tune-up for each EGU. The 
date of the tune-up is the date the tune-up provisions specified in 
Sec.  63.10021(e)(6) and (7) were completed.
    (5) Should you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, for each instance of 
startup or shutdown you shall:
    (i) Include the maximum clean fuel storage capacity and the maximum 
hourly heat input that can be provided for each clean fuel determined 
according to the requirements of Sec.  63.10032(f).
    (ii) Include the information required to be monitored, collected, 
or recorded according to the requirements of Sec.  63.10020(e).
    (iii) If you choose to use CEMS to demonstrate compliance with 
numerical limits, include hourly average CEMS values and hourly average 
flow values during startup periods or shutdown periods. Use units of 
milligrams per cubic meter for PM CEMS values, micrograms per cubic 
meter for Hg CEMS values, and ppmv for HCl, HF, or

[[Page 20189]]

SO2 CEMS values. Use units of standard cubic meters per hour 
on a wet basis for flow values.
    (iv) If you choose to use a separate sorbent trap measurement 
system for startup or shutdown reporting periods, include hourly 
average mercury concentration values in terms of micrograms per cubic 
meter.
    (v) If you choose to use a PM CPMS, include hourly average 
operating parameter values in terms of the operating limit, as well as 
the operating parameter to PM correlation equation.
    (6) You must report emergency bypass information annually from EGUs 
with LEE status.
    (7) A summary of the results of the annual performance tests and 
documentation of any operating limits that were reestablished during 
the test, if applicable. If you are conducting stack tests once every 3 
years to maintain LEE status, consistent with Sec.  63.10006(b), the 
date of each stack test conducted during the previous 3 years, a 
comparison of emission level you achieved in each stack test conducted 
during the previous 3 years to the 50 percent emission limit threshold 
required in Sec.  63.10005(h)(1)(i), and a statement as to whether 
there have been any operational changes since the last stack test that 
could increase emissions.
    (8) A certification.
    (9) If you have a deviation from any emission limit, work practice 
standard, or operating limit, you must also submit a brief description 
of the deviation, the duration of the deviation, emissions point 
identification, and the cause of the deviation.
* * * * *

0
19. Section 63.10032 is amended by revising paragraph (f) to read as 
follows:


Sec.  63.10032  What records must I keep?

* * * * *
    (f) Regarding startup periods or shutdown periods:
    (1) Should you choose to rely on paragraph (1) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, you must keep records of 
the occurrence and duration of each startup or shutdown.
    (2) Should you choose to rely on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042 for your EGU, you must keep records of:
    (i) The determination of the maximum possible clean fuel capacity 
for each EGU;
    (ii) The determination of the maximum possible hourly clean fuel 
heat input and of the hourly clean fuel heat input for each EGU; and
    (iii) The information required in Sec.  63.10020(e).
* * * * *

0
20. Section 63.10042 is amended by:
0
a. Revising the definitions of ``Coal-fired electric utility steam 
generating unit,'' ``Coal refuse,'' ``Fossil fuel-fired,'' ``Integrated 
gasification combined cycle electric utility steam generating unit or 
IGCC,'' ``Limited-use liquid oil-fired subcategory,'' and ``Natural 
gas-fired electric utility steam generating unit'';
0
b. Adding, in alphabetical order, definition of ``Neural network or 
neural net''; and
0
c. Revising the definition of ``Oil-fired electric utility steam 
generating unit.''
    The revisions and additions read as follows:


Sec.  63.10042  What definitions apply to this subpart?

* * * * *
    Coal-fired electric utility steam generating unit means an electric 
utility steam generating unit meeting the definition of ``fossil fuel-
fired'' that burns coal for more than 10.0 percent of the average 
annual heat input during the 3 previous calendar years after the 
compliance date for your facility in Sec.  63.9984 or for more than 
15.0 percent of the annual heat input during any one of those calendar 
years. EGU owners and operators must estimate coal, oil, and natural 
gas usage for the first 3 calendar years after the applicable 
compliance date and they are solely responsible for assuring compliance 
with this final rule or other applicable standard based on their fuel 
usage projections. After the first 3 years of compliance, EGUs are 
required to evaluate applicability based on coal or oil usage from the 
three previous calendars years on an annual rolling basis.
    Coal refuse means waste products of coal mining, physical coal 
cleaning, and coal preparation operations (e.g. culm, gob, etc.) 
containing coal, matrix material, clay, and other organic and inorganic 
material.
* * * * *
    Fossil fuel-fired means an electric utility steam generating unit 
(EGU) that is capable of producing more than 25 MW of electrical output 
from the combustion of fossil fuels. To be ``capable of combusting'' 
fossil fuels, an EGU would need to have these fuels allowed in its 
operating permit and have the appropriate fuel handling facilities on-
site or otherwise available (e.g., coal handling equipment, including 
coal storage area, belts and conveyers, pulverizers, etc.; oil storage 
facilities). In addition, fossil fuel-fired means any EGU that fired 
fossil fuels for more than 10.0 percent of the average annual heat 
input during the 3 previous calendar years after the compliance date 
for your facility in Sec.  63.9984 or for more than 15.0 percent of the 
annual heat input during any one of those calendar years. EGU owners 
and operators must estimate coal, oil, and natural gas usage for the 
first 3 calendar years after the applicable compliance date and they 
are solely responsible for assuring compliance with this final rule or 
other applicable standard based on their fuel usage projections. After 
the first 3 years of compliance, EGUs are required to evaluate 
applicability based on coal or oil usage from the three previous 
calendars years on an annual rolling basis.
* * * * *
    Integrated gasification combined cycle electric utility steam 
generating unit or IGCC means an electric utility steam generating unit 
meeting the definition of ``fossil fuel-fired'' that burns a synthetic 
gas derived from coal and/or solid oil-derived fuel for more than 10.0 
percent of the average annual heat input during the 3 previous calendar 
years after the compliance date for your facility in Sec.  63.9984 or 
for more than 15.0 percent of the annual heat input during any one of 
those calendar years in a combined-cycle gas turbine. EGU owners and 
operators must estimate coal, oil, and natural gas usage for the first 
3 calendar years after the applicable compliance date and they are 
solely responsible for assuring compliance with this final rule or 
other applicable standard based on their fuel usage projections. No 
solid coal or solid oil-derived fuel is directly burned in the unit 
during operation. After the first 3 years of compliance, EGUs are 
required to evaluate applicability based on coal or oil usage from the 
three previous calendars years on an annual rolling basis.
* * * * *
    Limited-use liquid oil-fired subcategory means an oil-fired 
electric utility steam generating unit with an annual capacity factor 
when burning oil of less than 8 percent of its maximum or nameplate 
heat input, whichever is greater, averaged over a 24-month block 
contiguous period commencing on the first of the month following the 
compliance date specified in Sec.  63.9984.
* * * * *
    Natural gas-fired electric utility steam generating unit means an 
electric utility steam generating unit meeting the definition of 
``fossil fuel-fired'' that is not a coal-fired, oil-fired, or IGCC 
electric utility steam generating unit and

[[Page 20190]]

that burns natural gas for more than 10.0 percent of the average annual 
heat input during the 3 previous calendar years after the compliance 
date for your facility in Sec.  63.9984 or for more than 15.0 percent 
of the annual heat input during any one of those calendar years. EGU 
owners and operators must estimate coal, oil, and natural gas usage for 
the first 3 calendar years after the applicable compliance date and 
they are solely responsible for assuring compliance with this final 
rule or other applicable standard based on their fuel usage 
projections.
* * * * *
    Neural network or neural net for purposes of this rule means an 
automated boiler optimization system. A neural network typically has 
the ability to process data from many inputs to develop, remember, 
update, and enable algorithms for efficient boiler operation.
* * * * *
    Oil-fired electric utility steam generating unit means an electric 
utility steam generating unit meeting the definition of ``fossil fuel-
fired'' that is not a coal-fired electric utility steam generating unit 
and that burns oil for more than 10.0 percent of the average annual 
heat input during the 3 previous calendar years after the compliance 
date for your facility in Sec.  63.9984 or for more than 15.0 percent 
of the annual heat input during any one of those calendar years. EGU 
owners and operators must estimate coal, oil, and natural gas usage for 
the first 3 calendar years after the applicable compliance date and 
they are solely responsible for assuring compliance with this final 
rule or other applicable standard based on their fuel usage 
projections. After the first 3 years of compliance, EGUs are required 
to evaluate applicability based on coal or oil usage from the three 
previous calendars years on an annual rolling basis.
* * * * *

0
21. Revise Table 1 to subpart UUUUU of part 63 to read as follows:

               Table 1 to Subpart UUUUU of Part 63--Emission Limits for New or Reconstructed EGUs
          [As stated in Sec.   63.9991, you must comply with the following applicable emission limits:]
----------------------------------------------------------------------------------------------------------------
                                                                                               Using these
                                                                                             requirements, as
                                                                   You must meet the        appropriate (e.g.,
                                                                   following emission       specified sampling
If your EGU is in this  subcategory .     For the following         limits and work         volume or test run
                 . .                       pollutants . . .      practice standards . .       duration) and
                                                                           .               limitations with the
                                                                                          test  methods in Table
                                                                                         5 to this Subpart . . .
----------------------------------------------------------------------------------------------------------------
1. Coal-fired unit not low rank        a. Filterable            9.0E-2 lb/MWh \1\......  Collect a minimum of 4
 virgin coal.                           particulate matter                                dscm per run.
                                        (PM).
                                       OR.....................  OR                       .......................
                                       Total non-Hg HAP metals  6.0E-2 lb/GWh..........  Collect a minimum of 4
                                                                                          dscm per run.
                                       OR.....................  OR                       .......................
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-3 lb/GWh..........  .......................
                                       Arsenic (As)...........  3.0E-3 lb/GWh..........  .......................
                                       Beryllium (Be).........  6.0E-4 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  4.0E-4 lb/GWh..........  .......................
                                       Chromium (Cr)..........  7.0E-3 lb/GWh..........  .......................
                                       Cobalt (Co)............  2.0E-3 lb/GWh..........  .......................
                                       Lead (Pb)..............  2.0E-2 lb/GWh..........  .......................
                                       Manganese (Mn).........  4.0E-3 lb/GWh..........  .......................
                                       Nickel (Ni)............  4.0E-2 lb/GWh..........  .......................
                                       Selenium (Se)..........  5.0E-2 lb/GWh..........  .......................
                                       b. Hydrogen chloride     1.0E-2 lb/MWh..........  For Method 26A at
                                        (HCl).                                            appendix A-8 to part
                                                                                          60 of this chapter,
                                                                                          collect a minimum of 3
                                                                                          dscm per run. For ASTM
                                                                                          D6348-03 \2\ or Method
                                                                                          320 at appendix A to
                                                                                          part 63 of this
                                                                                          chapter, sample for a
                                                                                          minimum of 1 hour.
                                       OR
                                       Sulfur dioxide (SO2)     1.0 lb/MWh.............  SO2 CEMS.
                                        \3\.
                                       c. Mercury (Hg)........  3.0E-3 lb/GWh..........  Hg CEMS or sorbent trap
                                                                                          monitoring system
                                                                                          only.
2. Coal-fired units low rank virgin    a. Filterable            9.0E-2 lb/MWh \1\......  Collect a minimum of 4
 coal.                                  particulate matter                                dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  6.0E-2 lb/GWh..........  Collect a minimum of 4
                                                                                          dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-3 lb/GWh..........  .......................
                                       Arsenic (As)...........  3.0E-3 lb/GWh..........  .......................
                                       Beryllium (Be).........  6.0E-4 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  4.0E-4 lb/GWh..........  .......................
                                       Chromium (Cr)..........  7.0E-3 lb/GWh..........  .......................
                                       Cobalt (Co)............  2.0E-3 lb/GWh..........  .......................
                                       Lead (Pb)..............  2.0E-2 lb/GWh..........  .......................
                                       Manganese (Mn).........  4.0E-3 lb/GWh..........  .......................
                                       Nickel (Ni)............  4.0E-2 lb/GWh..........  .......................
                                       Selenium (Se)..........  5.0E-2 lb/GWh..........  .......................
                                       b. Hydrogen chloride     1.0E-2 lb/MWh..........  For Method 26A, collect
                                        (HCl).                                            a minimum of 3 dscm
                                                                                          per run For ASTM D6348-
                                                                                          03 \2\ or Method 320,
                                                                                          sample for a minimum
                                                                                          of 1 hour.
                                       OR

[[Page 20191]]

 
                                       Sulfur dioxide (SO2)     1.0 lb/MWh.............  SO2 CEMS.
                                        \3\.
                                       c. Mercury (Hg)........  4.0E-2 lb/GWh..........  Hg CEMS or sorbent trap
                                                                                          monitoring system
                                                                                          only.
3. IGCC unit.........................  a. Filterable            7.0E-2 lb/MWh \4\ 9.0E-  Collect a minimum of 1
                                        particulate matter       2 lb/MWh \5\.            dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  4.0E-1 lb/GWh..........  Collect a minimum of 1
                                                                                          dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 2
                                                                                          dscm per run.
                                       Antimony (Sb)..........  2.0E-2 lb/GWh..........  .......................
                                       Arsenic (As)...........  2.0E-2 lb/GWh..........  .......................
                                       Beryllium (Be).........  1.0E-3 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  2.0E-3 lb/GWh..........  .......................
                                       Chromium (Cr)..........  4.0E-2 lb/GWh..........  .......................
                                       Cobalt (Co)............  4.0E-3 lb/GWh..........  .......................
                                       Lead (Pb)..............  9.0E-3 lb/GWh..........  .......................
                                       Manganese (Mn).........  2.0E-2 lb/GWh..........  .......................
                                       Nickel (Ni)............  7.0E-2 lb/GWh..........  .......................
                                       Selenium (Se)..........  3.0E-1 lb/GWh..........  .......................
                                       b. Hydrogen chloride     2.0E-3 lb/MWh..........  For Method 26A, collect
                                        (HCl).                                            a minimum of 1 dscm
                                                                                          per run; for Method 26
                                                                                          at appendix A-8 to
                                                                                          part 60 of this
                                                                                          chapter, collect a
                                                                                          minimum of 120 liters
                                                                                          per run. For ASTM
                                                                                          D6348-03 \2\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 1 hour.
                                       OR
                                       Sulfur dioxide (SO2)     4.0E-1 lb/MWh..........  SO2 CEMS.
                                        \3\.
                                       c. Mercury (Hg)........  3.0E-3 lb/GWh..........  Hg CEMS or sorbent trap
                                                                                          monitoring system
                                                                                          only.
4. Liquid oil-fired unit--continental  a. Filterable            3.0E-1 lb/MWh \1\......  Collect a minimum of 1
 (excluding limited-use liquid oil-     particulate matter                                dscm per run.
 fired subcategory units).              (PM).
                                       OR.....................  OR
                                       Total HAP metals.......  2.0E-4 lb/MWh..........  Collect a minimum of 2
                                                                                          dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 2
                                                                                          dscm per run.
                                       Antimony (Sb)..........  1.0E-2 lb/GWh..........  .......................
                                       Arsenic (As)...........  3.0E-3 lb/GWh..........  .......................
                                       Beryllium (Be).........  5.0E-4 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  2.0E-4 lb/GWh..........  .......................
                                       Chromium (Cr)..........  2.0E-2 lb/GWh..........  .......................
                                       Cobalt (Co)............  3.0E-2 lb/GWh..........  .......................
                                       Lead (Pb)..............  8.0E-3 lb/GWh..........  .......................
                                       Manganese (Mn).........  2.0E-2 lb/GWh..........  .......................
                                       Nickel (Ni)............  9.0E-2 lb/GWh..........  .......................
                                       Selenium (Se)..........  2.0E-2 lb/GWh..........  .......................
                                       Mercury (Hg)...........  1.0E-4 lb/GWh..........  For Method 30B at
                                                                                          appendix A-8 to part
                                                                                          60 of this chapter
                                                                                          sample volume
                                                                                          determination (Section
                                                                                          8.2.4), the estimated
                                                                                          Hg concentration
                                                                                          should nominally be <
                                                                                          \1/2\ the standard.
                                       b. Hydrogen chloride     4.0E-4 lb/MWh..........  For Method 26A, collect
                                        (HCl).                                            a minimum of 3 dscm
                                                                                          per run. For ASTM
                                                                                          D6348-03 \2\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 1 hour.
                                       c. Hydrogen fluoride     4.0E-4 lb/MWh..........  For Method 26A, collect
                                        (HF).                                             a minimum of 3 dscm
                                                                                          per run. For ASTM
                                                                                          D6348-03 \2\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 1 hour.
5. Liquid oil-fired unit--non-         a. Filterable            2.0E-1 lb/MWh \1\......  Collect a minimum of 1
 continental (excluding limited-use     particulate matter                                dscm per run.
 liquid oil-fired subcategory units).   (PM).
                                       OR.....................  OR                       .......................
                                       Total HAP metals.......  7.0E-3 lb/MWh..........  Collect a minimum of 1
                                                                                          dscm per run.
                                       OR.....................  OR                       .......................
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.

[[Page 20192]]

 
                                       Antimony (Sb)..........  8.0E-3 lb/GWh..........  .......................
                                       Arsenic (As)...........  6.0E-2 lb/GWh..........  .......................
                                       Beryllium (Be).........  2.0E-3 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  2.0E-3 lb/GWh..........  .......................
                                       Chromium (Cr)..........  2.0E-2 lb/GWh..........  .......................
                                       Cobalt (Co)............  3.0E-1 lb/GWh..........  .......................
                                       Lead (Pb)..............  3.0E-2 lb/GWh..........  .......................
                                       Manganese (Mn).........  1.0E-1 lb/GWh..........  .......................
                                       Nickel (Ni)............  4.1E0 lb/GWh...........  .......................
                                       Selenium (Se)..........  2.0E-2 lb/GWh..........  .......................
                                       Mercury (Hg)...........  4.0E-4 lb/GWh..........  For Method 30B sample
                                                                                          volume determination
                                                                                          (Section 8.2.4), the
                                                                                          estimated Hg
                                                                                          concentration should
                                                                                          nominally be < \1/2\
                                                                                          the standard.
                                       b. Hydrogen chloride     2.0E-3 lb/MWh..........  For Method 26A, collect
                                        (HCl).                                            a minimum of 1 dscm
                                                                                          per run;for Method 26,
                                                                                          collect a minimum of
                                                                                          120 liters per run.
                                                                                          For ASTM D6348-03 \2\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 1
                                                                                          hour.
                                       c. Hydrogen fluoride     5.0E-4 lb/MWh..........  For Method 26A, collect
                                        (HF).                                             a minimum of 3 dscm
                                                                                          per run.For ASTM D6348-
                                                                                          03 \2\ or Method 320,
                                                                                          sample for a minimum
                                                                                          of 1 hour.
6. Solid oil-derived fuel-fired unit.  a. Filterable            3.0E-2 lb/MWh \1\......  Collect a minimum of 1
                                        particulate matter                                dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  6.0E-1 lb/GWh..........  Collect a minimum of 1
                                                                                          dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-3 lb/GWh..........  .......................
                                       Arsenic (As)...........  3.0E-3 lb/GWh..........  .......................
                                       Beryllium (Be).........  6.0E-4 lb/GWh..........  .......................
                                       Cadmium (Cd)...........  7.0E-4 lb/GWh..........  .......................
                                       Chromium (Cr)..........  6.0E-3 lb/GWh..........  .......................
                                       Cobalt (Co)............  2.0E-3 lb/GWh..........  .......................
                                       Lead (Pb)..............  2.0E-2 lb/GWh..........  .......................
                                       Manganese (Mn).........  7.0E-3 lb/GWh..........  .......................
                                       Nickel (Ni)............  4.0E-2 lb/GWh..........  .......................
                                       Selenium (Se)..........  6.0E-3 lb/GWh..........  .......................
                                       b. Hydrogen chloride     4.0E-4 lb/MWh..........  For Method 26A, collect
                                        (HCl).                                            a minimum of 3 dscm
                                                                                          per run. For ASTM
                                                                                          D6348-03 \2\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 1 hour.
                                       OR
                                       Sulfur dioxide (SO2)     1.0 lb/MWh.............  SO2 CEMS.
                                        \3\.
                                       c. Mercury (Hg)........  2.0E-3 lb/GWh..........  Hg CEMS or Sorbent trap
                                                                                          monitoring system
                                                                                          only.
----------------------------------------------------------------------------------------------------------------
\1\ Gross output.
\2\ Incorporated by reference, see Sec.   63.14.
\3\ You may not use the alternate SO2 limit if your EGU does not have some form of FGD system (or, in the case
  of IGCC EGUs, some other acid gas removal system either upstream or downstream of the combined cycle block)
  and SO2 CEMS installed.
\4\ Duct burners on syngas; gross output.
\5\ Duct burners on natural gas; gross output.


0
22. Revise Table 2 to subpart UUUUU of part 63 to read as follows:

[[Page 20193]]



                     Table 2 to Subpart UUUUU of Part 63--Emission Limits for Existing EGUs
        [As stated in Sec.   63.9991, you must comply with the following applicable emission limits: \1\]
----------------------------------------------------------------------------------------------------------------
                                                                                               Using these
                                                                                             requirements, as
                                                                   You must meet the        appropriate (e.g.,
                                                                   following emission       specified sampling
If your EGU is in this  subcategory .     For the following         limits and work         volume or test run
                 . .                       pollutants . . .      practice standards . .       duration) and
                                                                           .               limitations with the
                                                                                         test methods in Table 5
                                                                                          to this Subpart . . .
----------------------------------------------------------------------------------------------------------------
1. Coal-fired unit not low rank        a. Filterable            3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
 virgin coal.                           particulate matter       1 lb/MWh \2\.            dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  5.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
                                                                 1 lb/GWh.                dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-1 lb/TBtu or 8.0E-  .......................
                                                                 3 lb/GWh.
                                       Arsenic (As)...........  1.1E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Beryllium (Be).........  2.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 3 lb/GWh.
                                       Cadmium (Cd)...........  3.0E-1 lb/TBtu or 3.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  2.8E0 lb/TBtu or 3.0E-2  .......................
                                                                 lb/GWh.
                                       Cobalt (Co)............  8.0E-1 lb/TBtu or 8.0E-  .......................
                                                                 3 lb/GWh.
                                       Lead (Pb)..............  1.2E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Manganese (Mn).........  4.0E0 lb/TBtu or 5.0E-2  .......................
                                                                 lb/GWh.
                                       Nickel (Ni)............  3.5E0 lb/TBtu or 4.0E-2  .......................
                                                                 lb/GWh.
                                       Selenium (Se)..........  5.0E0 lb/TBtu or 6.0E-2  .......................
                                                                 lb/GWh.
                                       b. Hydrogen chloride     2.0E-3 lb/MMBtu or 2.0E- For Method 26A at
                                        (HCl).                   2 lb/MWh.                appendix A-8 to part
                                                                                          60 of this chapter,
                                                                                          collect a minimum of
                                                                                          0.75 dscm per run; for
                                                                                          Method 26, collect a
                                                                                          minimum of 120 liters
                                                                                          per run. For ASTM
                                                                                          D6348-03 \3\ or Method
                                                                                          320 at appendix A to
                                                                                          part 63 of this
                                                                                          chapter, sample for a
                                                                                          minimum of 1 hour.
                                       OR
                                       Sulfur dioxide (SO2)     2.0E-1 lb/MMBtu or       SO2 CEMS.
                                        \4\.                     1.5E0 lb/MWh.
                                       c. Mercury (Hg)........  1.2E0 lb/TBtu or 1.3E-2  LEE Testing for 30 days
                                                                 lb/GWh.                  with a sampling period
                                                                                          consistent with that
                                                                                          given in section 5.2.1
                                                                                          of appendix A to this
                                                                                          subpart per Method 30B
                                                                                          at appendix A-8 to
                                                                                          part 60 of this
                                                                                          chapter run or Hg CEMS
                                                                                          or sorbent trap
                                                                                          monitoring system
                                                                                          only.
                                                                OR.....................
                                                                1.0E0 lb/TBtu or 1.1E-2  LEE Testing for 90 days
                                                                 lb/GWh.                  with a sampling period
                                                                                          consistent with that
                                                                                          given in section 5.2.1
                                                                                          of appendix A to this
                                                                                          subpart per Method 30B
                                                                                          run or Hg CEMS or
                                                                                          sorbent trap
                                                                                          monitoring system
                                                                                          only.
2. Coal-fired unit low rank virgin     a. Filterable            3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
 coal.                                  particulate matter       1 lb/MWh \2\.            dscm per run.
                                        (PM).
                                       OR.....................  OR.....................
                                       Total non-Hg HAP metals  5.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
                                                                 1 lb/GWh.                dscm per run.
                                       OR.....................  OR.....................
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-1 lb/TBtu or 8.0E-  .......................
                                                                 3 lb/GWh.
                                       Arsenic (As)...........  1.1E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Beryllium (Be).........  2.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 3 lb/GWh.
                                       Cadmium (Cd)...........  3.0E-1 lb/TBtu or 3.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  2.8E0 lb/TBtu or 3.0E-2  .......................
                                                                 lb/GWh.
                                       Cobalt (Co)............  8.0E-1 lb/TBtu or 8.0E-  .......................
                                                                 3 lb/GWh.
                                       Lead (Pb)..............  1.2E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Manganese (Mn).........  4.0E0 lb/TBtu or 5.0E-2  .......................
                                                                 lb/GWh.
                                       Nickel (Ni)............  3.5E0 lb/TBtu or 4.0E-2  .......................
                                                                 lb/GWh.
                                       Selenium (Se)..........  5.0E0 lb/TBtu or 6.0E-2  .......................
                                                                 lb/GWh.

[[Page 20194]]

 
                                       b. Hydrogen chloride     2.0E-3 lb/MMBtu or 2.0E- For Method 26A, collect
                                        (HCl).                   2 lb/MWh.                a minimum of 0.75 dscm
                                                                                          per run; for Method 26
                                                                                          at appendix A-8 to
                                                                                          part 60 of this
                                                                                          chapter, collect a
                                                                                          minimum of 120 liters
                                                                                          per run. For ASTM
                                                                                          D6348-03 \3\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 1 hour.
                                       OR
                                       Sulfur dioxide (SO2)     2.0E-1 lb/MMBtu or       SO2 CEMS.
                                        \4\.                     1.5E0 lb/MWh.
                                       c. Mercury (Hg)........  4.0E0 lb/TBtu or 4.0E-2  LEE Testing for 30 days
                                                                 lb/GWh.                  with a sampling period
                                                                                          consistent with that
                                                                                          given in section 5.2.1
                                                                                          of appendix A to this
                                                                                          subpart per Method 30B
                                                                                          run or Hg CEMS or
                                                                                          sorbent trap
                                                                                          monitoring system
                                                                                          only.
3. IGCC unit.........................  a. Filterable            4.0E-2 lb/MMBtu or 4.0E- Collect a minimum of 1
                                        particulate matter       1 lb/MWh \2\.            dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  6.0E-5 lb/MMBtu or 5.0E- Collect a minimum of 1
                                                                 1 lb/GWh.                dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 2
                                                                                          dscm per run.
                                       Antimony (Sb)..........  1.4E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Arsenic (As)...........  1.5E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Beryllium (Be).........  1.0E-1 lb/TBtu or 1.0E-  .......................
                                                                 3 lb/GWh.
                                       Cadmium (Cd)...........  1.5E-1 lb/TBtu or 2.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  2.9E0 lb/TBtu or 3.0E-2  .......................
                                                                 lb/GWh.
                                       Cobalt (Co)............  1.2E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Lead (Pb)..............  1.9E+2 lb/TBtu or 1.8E0  .......................
                                                                 lb/GWh.
                                       Manganese (Mn).........  2.5E0 lb/TBtu or 3.0E-2  .......................
                                                                 lb/GWh.
                                       Nickel (Ni)............  6.5E0 lb/TBtu or 7.0E-2  .......................
                                                                 lb/GWh.
                                       Selenium (Se)..........  2.2E+1 lb/TBtu or 3.0E-  .......................
                                                                 1 lb/GWh.
                                       b. Hydrogen chloride     5.0E-4 lb/MMBtu or 5.0E- For Method 26A, collect
                                        (HCl).                   3 lb/MWh.                a minimum of 1 dscm
                                                                                          per run; for Method
                                                                                          26, collect a minimum
                                                                                          of 120 liters per run.
                                                                                          For ASTM D6348-03 \3\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 1
                                                                                          hour.
                                       c. Mercury (Hg)........  2.5E0 lb/TBtu or 3.0E-2  LEE Testing for 30 days
                                                                 lb/GWh.                  with a sampling period
                                                                                          consistent with that
                                                                                          given in section 5.2.1
                                                                                          of appendix A to this
                                                                                          subpart per Method 30B
                                                                                          run or Hg CEMS or
                                                                                          sorbent trap
                                                                                          monitoring system
                                                                                          only.
4. Liquid oil-fired unit--continental  a. Filterable            3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
 (excluding limited-use liquid oil-     particulate matter       1 lb/MWh \2\.            dscm per run.
 fired subcategory units).              (PM).
                                       OR.....................  OR
                                       Total HAP metals.......  8.0E-4 lb/MMBtu or 8.0E- Collect a minimum of 1
                                                                 3 lb/MWh.                dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 1
                                                                                          dscm per run.
                                       Antimony (Sb)..........  1.3E+1 lb/TBtu or 2.0E-  .......................
                                                                 1 lb/GWh.
                                       Arsenic (As)...........  2.8E0 lb/TBtu or 3.0E-2  .......................
                                                                 lb/GWh.
                                       Beryllium (Be).........  2.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 3 lb/GWh.
                                       Cadmium (Cd)...........  3.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  5.5E0 lb/TBtu or 6.0E-2  .......................
                                                                 lb/GWh.
                                       Cobalt (Co)............  2.1E+1 lb/TBtu or 3.0E-  .......................
                                                                 1 lb/GWh.
                                       Lead (Pb)..............  8.1E0 lb/TBtu or 8.0E-2  .......................
                                                                 lb/GWh.
                                       Manganese (Mn).........  2.2E+1 lb/TBtu or 3.0E-  .......................
                                                                 1 lb/GWh.
                                       Nickel (Ni)............  1.1E+2 lb/TBtu or 1.1E0  .......................
                                                                 lb/GWh.

[[Page 20195]]

 
                                       Selenium (Se)..........  3.3E0 lb/TBtu or 4.0E-2  .......................
                                                                 lb/GWh.
                                       Mercury (Hg)...........  2.0E-1 lb/TBtu or 2.0E-  For Method 30B sample
                                                                 3 lb/GWh.                volume determination
                                                                                          (Section 8.2.4), the
                                                                                          estimated Hg
                                                                                          concentration should
                                                                                          nominally be < \1/2\
                                                                                          the standard.
                                       b. Hydrogen chloride     2.0E-3 lb/MMBtu or 1.0E- For Method 26A, collect
                                        (HCl).                   2 lb/MWh.                a minimum of 1 dscm
                                                                                          per run; for Method
                                                                                          26, collect a minimum
                                                                                          of 120 liters per run.
                                                                                          For ASTM D6348-03 \3\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 1
                                                                                          hour.
                                       c. Hydrogen fluoride     4.0E-4 lb/MMBtu or 4.0E- For Method 26A, collect
                                        (HF).                    3 lb/MWh.                a minimum of 1 dscm
                                                                                          per run; for Method
                                                                                          26, collect a minimum
                                                                                          of 120 liters per run.
                                                                                          For ASTM D6348-03 \3\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 1
                                                                                          hour.
5. Liquid oil-fired unit--non-         a. Filterable            3.0E-2 lb/MMBtu or 3.0E- Collect a minimum of 1
 continental (excluding limited-use     particulate matter       1 lb/MWh \2\.            dscm per run.
 liquid oil-fired subcategory units).   (PM).
                                       OR.....................  OR
                                       Total HAP metals.......  6.0E-4 lb/MMBtu or 7.0E- Collect a minimum of 1
                                                                 3 lb/MWh.                dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 2
                                                                                          dscm per run.
                                       Antimony (Sb)..........  2.2E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Arsenic (As)...........  4.3E0 lb/TBtu or 8.0E-2  .......................
                                                                 lb/GWh.
                                       Beryllium (Be).........  6.0E-1 lb/TBtu or 3.0E-  .......................
                                                                 3 lb/GWh.
                                       Cadmium (Cd)...........  3.0E-1 lb/TBtu or 3.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  3.1E+1 lb/TBtu or 3.0E-  .......................
                                                                 1 lb/GWh.
                                       Cobalt (Co)............  1.1E+2 lb/TBtu or 1.4E0  .......................
                                                                 lb/GWh.
                                       Lead (Pb)..............  4.9E0 lb/TBtu or 8.0E-2  .......................
                                                                 lb/GWh.
                                       Manganese (Mn).........  2.0E+1 lb/TBtu or 3.0E-  .......................
                                                                 1 lb/GWh.
                                       Nickel (Ni)............  4.7E+2 lb/TBtu or 4.1E0  .......................
                                                                 lb/GWh.
                                       Selenium (Se)..........  9.8E0 lb/TBtu or 2.0E-1  .......................
                                                                 lb/GWh.
                                       Mercury (Hg)...........  4.0E-2 lb/TBtu or 4.0E-  For Method 30B sample
                                                                 4 lb/GWh.                volume determination
                                                                                          (Section 8.2.4), the
                                                                                          estimated Hg
                                                                                          concentration should
                                                                                          nominally be < \1/2\
                                                                                          the standard.
                                       b. Hydrogen chloride     2.0E-4 lb/MMBtu or 2.0E- For Method 26A, collect
                                        (HCl).                   3 lb/MWh.                a minimum of 1 dscm
                                                                                          per run; for Method
                                                                                          26, collect a minimum
                                                                                          of 120 liters per run.
                                                                                          For ASTM D6348-03 \3\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 2
                                                                                          hours.
                                       c. Hydrogen fluoride     6.0E-5 lb/MMBtu or 5.0E- For Method 26A, collect
                                        (HF).                    4 lb/MWh.                a minimum of 3 dscm
                                                                                          per run. For ASTM
                                                                                          D6348-03 \3\ or Method
                                                                                          320, sample for a
                                                                                          minimum of 2 hours.
6. Solid oil-derived fuel-fired unit.  a. Filterable            8.0E-3 lb/MMBtu or 9.0E- Collect a minimum of 1
                                        particulate matter       2 lb/MWh \2\.            dscm per run.
                                        (PM).
                                       OR.....................  OR
                                       Total non-Hg HAP metals  4.0E-5 lb/MMBtu or 6.0E- Collect a minimum of 1
                                                                 1 lb/GWh.                dscm per run.
                                       OR.....................  OR
                                       Individual HAP metals:.                           Collect a minimum of 3
                                                                                          dscm per run.
                                       Antimony (Sb)..........  8.0E-1 lb/TBtu or 7.0E-  .......................
                                                                 3 lb/GWh.
                                       Arsenic (As)...........  3.0E-1 lb/TBtu or 5.0E-  .......................
                                                                 3 lb/GWh.
                                       Beryllium (Be).........  6.0E-2 lb/TBtu or 5.0E-  .......................
                                                                 4 lb/GWh.

[[Page 20196]]

 
                                       Cadmium (Cd)...........  3.0E-1 lb/TBtu or 4.0E-  .......................
                                                                 3 lb/GWh.
                                       Chromium (Cr)..........  8.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 2 lb/GWh.
                                       Cobalt (Co)............  1.1E0 lb/TBtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       Lead (Pb)..............  8.0E-1 lb/TBtu or 2.0E-  .......................
                                                                 2 lb/GWh.
                                       Manganese (Mn).........  2.3E0 lb/TBtu or 4.0E-2  .......................
                                                                 lb/GWh.
                                       Nickel (Ni)............  9.0E0 lb/TBtu or 2.0E-1  .......................
                                                                 lb/GWh.
                                       Selenium (Se)..........  1.2E0 lb/Tbtu or 2.0E-2  .......................
                                                                 lb/GWh.
                                       b. Hydrogen chloride     5.0E-3 lb/MMBtu or 8.0E- For Method 26A, collect
                                        (HCl).                   2 lb/MWh.                a minimum of 0.75 dscm
                                                                                          per run; for Method
                                                                                          26, collect a minimum
                                                                                          of 120 liters per run.
                                                                                          For ASTM D6348-03 \3\
                                                                                          or Method 320, sample
                                                                                          for a minimum of 1
                                                                                          hour.
                                       OR
                                       Sulfur dioxide (SO2)     3.0E-1 lb/MMBtu or       SO2 CEMS.
                                        \4\.                     2.0E0 lb/MWh.
                                       c. Mercury (Hg)........  2.0E-1 lb/TBtu or 2.0E-  LEE Testing for 30 days
                                                                 3 lb/GWh.                with a sampling period
                                                                                          consistent with that
                                                                                          given in section 5.2.1
                                                                                          of appendix A to this
                                                                                          subpart per Method 30B
                                                                                          run or Hg CEMS or
                                                                                          sorbent trap
                                                                                          monitoring system
                                                                                          only.
----------------------------------------------------------------------------------------------------------------
\1\ For LEE emissions testing for total PM, total HAP metals, individual HAP metals, HCl, and HF, the required
  minimum sampling volume must be increased nominally by a factor of two.
\2\ Gross output.
\3\ Incorporated by reference, see Sec.   63.14.
\4\ You may not use the alternate SO2 limit if your EGU does not have some form of FGD system and SO2 CEMS
  installed.


0
23. Revise Table 3 to subpart UUUUU of part 63 to read as follows:

      Table 3 to Subpart UUUUU of Part 63--Work Practice Standards
    [As stated in Sec.   63.9991, you must comply with the following
                  applicable work practice standards:]
------------------------------------------------------------------------
       If your EGU is . . .           You must meet the following . . .
------------------------------------------------------------------------
1. An existing EGU................  Conduct a tune-up of the EGU burner
                                     and combustion controls at least
                                     each 36 calendar months, or each 48
                                     calendar months if neural network
                                     combustion optimization software is
                                     employed, as specified in Sec.
                                     63.10021(e).
2. A new or reconstructed EGU.....  Conduct a tune-up of the EGU burner
                                     and combustion controls at least
                                     each 36 calendar months, or each 48
                                     calendar months if neural network
                                     combustion optimization software is
                                     employed, as specified in Sec.
                                     63.10021(e).
3. A coal-fired, liquid oil-fired   a. You have the option of complying
 (excluding limited-use liquid oil-  using either of the following work
 fired subcategory units), or        practice standards:
 solid oil-derived fuel-fired EGU   (1) If you choose to comply using
 during startup.                     paragraph (1) of the definition of
                                     ``startup'' in Sec.   63.10042, you
                                     must operate all CMS during
                                     startup. Startup means either the
                                     first-ever firing of fuel in a
                                     boiler for the purpose of producing
                                     electricity, or the firing of fuel
                                     in a boiler after a shutdown event
                                     for any purpose. Startup ends when
                                     any of the steam from the boiler is
                                     used to generate electricity for
                                     sale over the grid or for any other
                                     purpose (including on site use).
                                     For startup of a unit, you must use
                                     clean fuels as defined in Sec.
                                     63.10042 for ignition. Once you
                                     convert to firing coal, residual
                                     oil, or solid oil-derived fuel, you
                                     must engage all of the applicable
                                     control technologies except dry
                                     scrubber and SCR. You must start
                                     your dry scrubber and SCR systems,
                                     if present, appropriately to comply
                                     with relevant standards applicable
                                     during normal operation. You must
                                     comply with all applicable
                                     emissions limits at all times
                                     except for periods that meet the
                                     applicable definitions of startup
                                     and shutdown in this subpart. You
                                     must keep records during startup
                                     periods. You must provide reports
                                     concerning activities and startup
                                     periods, as specified in Sec.
                                     63.10011(g) and Sec.   63.10021(h)
                                     and (i).
                                       (2) If you choose to comply using
                                        paragraph (2) of the definition
                                        of ``startup'' in Sec.
                                        63.10042, you must operate all
                                        CMS during startup. You must
                                        also collect appropriate data,
                                        and you must calculate the
                                        pollutant emission rate for each
                                        hour of startup.
                                       For startup of an EGU, you must
                                        use one or a combination of the
                                        clean fuels defined in Sec.
                                        63.10042 to the maximum extent
                                        possible, taking into account
                                        considerations such as boiler or
                                        control device integrity,
                                        throughout the startup period.
                                        You must have sufficient clean
                                        fuel capacity to engage and
                                        operate your PM control device
                                        within one hour of adding coal,
                                        residual oil, or solid oil-
                                        derived fuel to the unit. You
                                        must meet the startup period
                                        work practice requirements as
                                        identified in Sec.
                                        63.10020(e).
                                       Once you start firing coal,
                                        residual oil, or solid oil-
                                        derived fuel, you must vent
                                        emissions to the main stack(s).
                                        You must comply with the
                                        applicable emission limits
                                        beginning with the hour after
                                        startup ends. You must engage
                                        and operate your particulate
                                        matter control(s) within 1 hour
                                        of first firing of coal,
                                        residual oil, or solid oil-
                                        derived fuel.

[[Page 20197]]

 
                                       You must start all other
                                        applicable control devices as
                                        expeditiously as possible,
                                        considering safety and
                                        manufacturer/supplier
                                        recommendations, but, in any
                                        case, when necessary to comply
                                        with other standards made
                                        applicable to the EGU by a
                                        permit limit or a rule other
                                        than this Subpart that require
                                        operation of the control
                                        devices.
                                       b. Relative to the syngas not
                                        fired in the combustion turbine
                                        of an IGCC EGU during startup,
                                        you must either: (1) Flare the
                                        syngas, or (2) route the syngas
                                        to duct burners, which may need
                                        to be installed, and route the
                                        flue gas from the duct burners
                                        to the heat recovery steam
                                        generator.
                                       c. If you choose to use just one
                                        set of sorbent traps to
                                        demonstrate compliance with the
                                        applicable Hg emission limit,
                                        you must comply with the limit
                                        at all times; otherwise, you
                                        must comply with the applicable
                                        emission limit at all times
                                        except for startup and shutdown
                                        periods.
                                       d. You must collect monitoring
                                        data during startup periods, as
                                        specified in Sec.   63.10020(a)
                                        and (e). You must keep records
                                        during startup periods, as
                                        provided in Sec.  Sec.
                                        63.10032 and 63.10021(h). You
                                        must provide reports concerning
                                        activities and startup periods,
                                        as specified in Sec.  Sec.
                                        63.10011(g), 63.10021(i), and
                                        63.10031.
4. A coal-fired, liquid oil-fired   You must operate all CMS during
 (excluding limited-use liquid oil-  shutdown. You must also collect
 fired subcategory units), or        appropriate data, and you must
 solid oil-derived fuel-fired EGU    calculate the pollutant emission
 during shutdown.                    rate for each hour of shutdown for
                                     those pollutants for which a CMS is
                                     used.
                                    While firing coal, residual oil, or
                                     solid oil-derived fuel during
                                     shutdown, you must vent emissions
                                     to the main stack(s) and operate
                                     all applicable control devices and
                                     continue to operate those control
                                     devices after the cessation of
                                     coal, residual oil, or solid oil-
                                     derived fuel being fed into the EGU
                                     and for as long as possible
                                     thereafter considering operational
                                     and safety concerns. In any case,
                                     you must operate your controls when
                                     necessary to comply with other
                                     standards made applicable to the
                                     EGU by a permit limit or a rule
                                     other than this Subpart and that
                                     require operation of the control
                                     devices.
                                       If, in addition to the fuel used
                                        prior to initiation of shutdown,
                                        another fuel must be used to
                                        support the shutdown process,
                                        that additional fuel must be one
                                        or a combination of the clean
                                        fuels defined in Sec.   63.10042
                                        and must be used to the maximum
                                        extent possible, taking into
                                        account considerations such as
                                        not compromising boiler or
                                        control device integrity.
                                       Relative to the syngas not fired
                                        in the combustion turbine of an
                                        IGCC EGU during shutdown, you
                                        must either: (1) Flare the
                                        syngas, or (2) route the syngas
                                        to duct burners, which may need
                                        to be installed, and route the
                                        flue gas from the duct burners
                                        to the heat recovery steam
                                        generator.
                                       You must comply with all
                                        applicable emission limits at
                                        all times except during startup
                                        periods and shutdown periods at
                                        which time you must meet this
                                        work practice. You must collect
                                        monitoring data during shutdown
                                        periods, as specified in Sec.
                                        63.10020(a). You must keep
                                        records during shutdown periods,
                                        as provided in Sec.  Sec.
                                        63.10032 and 63.10021(h). Any
                                        fraction of an hour in which
                                        shutdown occurs constitutes a
                                        full hour of shutdown. You must
                                        provide reports concerning
                                        activities and shutdown periods,
                                        as specified in Sec.  Sec.
                                        63.10011(g), 63.10021(i), and
                                        63.10031.
------------------------------------------------------------------------


0
24. Revise Table 4 to subpart UUUUU of part 63 to read as follows:

    Table 4 to Subpart UUUUU of Part 63 -- Operating Limits for EGUs
    [As stated in Sec.   63.9991, you must comply with the applicable
                           operating limits:]
------------------------------------------------------------------------
   If you demonstrate compliance    You must meet these operating limits
            using . . .                             . . .
------------------------------------------------------------------------
PM CPMS...........................  Maintain the 30-boiler operating day
                                     rolling average PM CPMS output
                                     determined in accordance with the
                                     requirements of Sec.
                                     63.10023(b)(2) and obtained during
                                     the most recent performance test
                                     run demonstrating compliance with
                                     the filterable PM, total non-
                                     mercury HAP metals (total HAP
                                     metals, for liquid oil-fired
                                     units), or individual non-mercury
                                     HAP metals (individual HAP metals
                                     including Hg, for liquid oil-fired
                                     units) emissions limitation(s).
------------------------------------------------------------------------


0
25. Revise Table 5 to subpart UUUUU of part 63 to read as follows:

                      Table 5 to Subpart UUUUU of Part 63--Performance Testing Requirements
   [As stated in Sec.   63.10007, you must comply with the following requirements for performance testing for
                              existing, new or reconstructed affected sources: \1\]
----------------------------------------------------------------------------------------------------------------
                                                                  You must perform the
                                                                 following activities,
To conduct a performance test for the        Using . . .         as applicable to your        Using . . .\2\
      following pollutant . . .                                  input- or output-based
                                                                  emission limit . . .
----------------------------------------------------------------------------------------------------------------
1. Filterable Particulate matter (PM)  Emissions Testing......  a. Select sampling       Method 1 at appendix A-
                                                                 ports location and the   1 to part 60 of this
                                                                 number of traverse       chapter.
                                                                 points.
                                                                b. Determine velocity    Method 2, 2A, 2C, 2F,
                                                                 and volumetric flow-     2G or 2H at appendix A-
                                                                 rate of the stack gas.   1 or A-2 to part 60 of
                                                                                          this chapter.

[[Page 20198]]

 
                                                                c. Determine oxygen and  Method 3A or 3B at
                                                                 carbon dioxide           appendix A-2 to part
                                                                 concentrations of the    60 of this chapter, or
                                                                 stack gas.               ANSI/ASME PTC 19.10-
                                                                                          1981.\3\
                                                                d. Measure the moisture  Method 4 at appendix A-
                                                                 content of the stack     3 to part 60 of this
                                                                 gas.                     chapter.
                                                                e. Measure the           Method 5 at appendix A-
                                                                 filterable PM            3 to part 60 of this
                                                                 concentration.           chapter.
                                                                                         For positive pressure
                                                                                          fabric filters, Method
                                                                                          5D at appendix A-3 to
                                                                                          part 60 of this
                                                                                          chapter for filterable
                                                                                          PM emissions.
                                                                                         Note that the Method 5
                                                                                          front half temperature
                                                                                          shall be 160[deg]
                                                                                           14[deg] C
                                                                                          (320[deg] 
                                                                                          25[deg] F).
                                                                f. Convert emissions     Method 19 F-factor
                                                                 concentration to lb/     methodology at
                                                                 MMBtu or lb/MWh          appendix A-7 to part
                                                                 emissions rates.         60 of this chapter, or
                                                                                          calculate using mass
                                                                                          emissions rate and
                                                                                          gross output data (see
                                                                                          Sec.   63.10007(e)).
                                       OR.....................     OR..................
                                       PM CEMS................  a. Install, certify,     Performance
                                                                 operate, and maintain    Specification 11 at
                                                                 the PM CEMS.             appendix B to part 60
                                                                                          of this chapter and
                                                                                          Procedure 2 at
                                                                                          appendix F to part 60
                                                                                          of this chapter.
                                                                b. Install, certify,     Part 75 of this chapter
                                                                 operate, and maintain    and Sec.
                                                                 the diluent gas, flow    63.10010(a), (b), (c),
                                                                 rate, and/or moisture    and (d).
                                                                 monitoring systems.
                                                                c. Convert hourly        Method 19 F-factor
                                                                 emissions                methodology at
                                                                 concentrations to 30     appendix A-7 to part
                                                                 boiler operating day     60 of this chapter, or
                                                                 rolling average lb/      calculate using mass
                                                                 MMBtu or lb/MWh          emissions rate and
                                                                 emissions rates.         gross output data (see
                                                                                          Sec.   63.10007(e)).
2. Total or individual non-Hg HAP      Emissions Testing......  a. Select sampling       Method 1 at appendix A-
 metals.                                                         ports location and the   1 to part 60 of this
                                                                 number of traverse       chapter.
                                                                 points..
                                                                b. Determine velocity    Method 2, 2A, 2C, 2F,
                                                                 and volumetric flow-     2G or 2H at appendix A-
                                                                 rate of the stack gas.   1 or A-2 to part 60 of
                                                                                          this chapter.
                                                                c. Determine oxygen and  Method 3A or 3B at
                                                                 carbon dioxide           appendix A-2 to part
                                                                 concentrations of the    60 of this chapter, or
                                                                 stack gas.               ANSI/ASME PTC 19.10-
                                                                                          1981.\3\
                                                                d. Measure the moisture  Method 4 at appendix A-
                                                                 content of the stack     3 to part 60 of this
                                                                 gas.                     chapter.
                                                                e. Measure the HAP       Method 29 at appendix A-
                                                                 metals emissions         8 to part 60 of this
                                                                 concentrations and       chapter. For liquid
                                                                 determine each           oil-fired units, Hg is
                                                                 individual HAP metals    included in HAP metals
                                                                 emissions                and you may use Method
                                                                 concentration, as well   29, Method 30B at
                                                                 as the total             appendix A-8 to part
                                                                 filterable HAP metals    60 of this chapter;
                                                                 emissions                for Method 29, you
                                                                 concentration and        must report the front
                                                                 total HAP metals         half and back half
                                                                 emissions                results separately.
                                                                 concentration.           When using Method 29,
                                                                                          report metals matrix
                                                                                          spike and recovery
                                                                                          levels.
                                                                f. Convert emissions     Method 19 F-factor
                                                                 concentrations           methodology at
                                                                 (individual HAP          appendix A-7 to part
                                                                 metals, total            60 of this chapter, or
                                                                 filterable HAP metals,   calculate using mass
                                                                 and total HAP metals)    emissions rate and
                                                                 to lb/MMBtu or lb/MWh    gross output data (see
                                                                 emissions rates.         Sec.   63.10007(e)).
3. Hydrogen chloride (HCl) and         Emissions Testing......  a. Select sampling       Method 1 at appendix A-
 hydrogen fluoride (HF).                                         ports location and the   1 to part 60 of this
                                                                 number of traverse       chapter.
                                                                 points..
                                                                b. Determine velocity    Method 2, 2A, 2C, 2F,
                                                                 and volumetric flow-     2G or 2H at appendix A-
                                                                 rate of the stack gas.   1 or A-2 to part 60 of
                                                                                          this chapter.
                                                                c. Determine oxygen and  Method 3A or 3B at
                                                                 carbon dioxide           appendix A-2 to part
                                                                 concentrations of the    60 of this chapter, or
                                                                 stack gas.               ANSI/ASME PTC 19.10-
                                                                                          1981.\3\
                                                                d. Measure the moisture  Method 4 at appendix A-
                                                                 content of the stack     3 to part 60 of this
                                                                 gas.                     chapter.

[[Page 20199]]

 
                                                                e. Measure the HCl and   Method 26 or Method 26A
                                                                 HF emissions             at appendix A-8 to
                                                                 concentrations.          part 60 of this
                                                                                          chapter or Method 320
                                                                                          at appendix A to part
                                                                                          63 of this chapter or
                                                                                          ASTM 6348-03 \3\ with
                                                                                         (1) the following
                                                                                          conditions when using
                                                                                          ASTM D6348-03:
                                                                                         (A) The test plan
                                                                                          preparation and
                                                                                          implementation in the
                                                                                          Annexes to ASTM D6348-
                                                                                          03, Sections A1
                                                                                          through A8 are
                                                                                          mandatory;
                                                                                         (B) For ASTM D6348-03
                                                                                          Annex A5 (Analyte
                                                                                          Spiking Technique),
                                                                                          the percent (%) R must
                                                                                          be determined for each
                                                                                          target analyte (see
                                                                                          Equation A5.5);
                                                                                         (C) For the ASTM D6348-
                                                                                          03 test data to be
                                                                                          acceptable for a
                                                                                          target analyte, %R
                                                                                          must be 70% >= R <=
                                                                                          130%; and
----------------------------------------------------------------------------------------------------------------

    3.e.1(D) The %R value for each compound must be reported in the 
test report and all field measurements corrected with the calculated %R 
value for that compound using the following equation:

[GRAPHIC] [TIFF OMITTED] TR06AP16.007

    and

----------------------------------------------------------------------------------------------------------------
                                                                  You must perform the
                                                                 following activities,
To conduct a performance test for the                            as applicable to your   Using . . .\2\ (cont'd)
  following pollutant . . . (cont'd)     Using . . . (cont'd)    input- or output-based
                                                                  emission limit . . .
                                                                        (cont'd)
----------------------------------------------------------------------------------------------------------------
                                       .......................  .......................  (2) spiking levels
                                                                                          nominally no greater
                                                                                          than two times the
                                                                                          level corresponding to
                                                                                          the applicable
                                                                                          emission limit.
                                                                                         Method 26A must be used
                                                                                          if there are entrained
                                                                                          water droplets in the
                                                                                          exhaust stream.
                                       .......................  f. Convert emissions     Method 19 F-factor
                                                                 concentration to lb/     methodology at
                                                                 MMBtu or lb/MWh          appendix A-7 to part
                                                                 emissions rates.         60 of this chapter, or
                                                                                          calculate using mass
                                                                                          emissions rate and
                                                                                          gross output data (see
                                                                                          Sec.   63.10007(e)).
                                       OR.....................  OR.....................
                                       HCl and/or HF CEMS.....  a. Install, certify,     Appendix B of this
                                                                 operate, and maintain    subpart.
                                                                 the HCl or HF CEMS.
                                       .......................  b. Install, certify,     Part 75 of this chapter
                                                                 operate, and maintain    and Sec.
                                                                 the diluent gas, flow    63.10010(a), (b), (c),
                                                                 rate, and/or moisture    and (d).
                                                                 monitoring systems.
                                       .......................  c. Convert hourly        Method 19 F-factor
                                                                 emissions                methodology at
                                                                 concentrations to 30     appendix A-7 to part
                                                                 boiler operating day     60 of this chapter, or
                                                                 rolling average lb/      calculate using mass
                                                                 MMBtu or lb/MWh          emissions rate and
                                                                 emissions rates.         gross output data (see
                                                                                          Sec.   63.10007(e)).
4. Mercury (Hg)......................  Emissions Testing......  a. Select sampling       Method 1 at appendix A-
                                                                 ports location and the   1 to part 60 of this
                                                                 number of traverse       chapter or Method 30B
                                                                 points.                  at Appendix A-8 for
                                                                                          Method 30B point
                                                                                          selection.
                                       .......................  b. Determine velocity    Method 2, 2A, 2C, 2F,
                                                                 and volumetric flow-     2G or 2H at appendix A-
                                                                 rate of the stack gas.   1 or A-2 to part 60 of
                                                                                          this chapter.
                                       .......................  c. Determine oxygen and  Method 3A or 3B at
                                                                 carbon dioxide           appendix A-1 to part
                                                                 concentrations of the    60 of this chapter, or
                                                                 stack gas.               ANSI/ASME PTC 19.10-
                                                                                          1981.\3\

[[Page 20200]]

 
                                       .......................  d. Measure the moisture  Method 4 at appendix A-
                                                                 content of the stack     3 to part 60 of this
                                                                 gas.                     chapter.
                                       .......................  e. Measure the Hg        Method 30B at appendix
                                                                 emission concentration.  A-8 to part 60 of this
                                                                                          chapter, ASTM
                                                                                          D6784,\3\ or Method 29
                                                                                          at appendix A-8 to
                                                                                          part 60 of this
                                                                                          chapter; for Method
                                                                                          29, you must report
                                                                                          the front half and
                                                                                          back half results
                                                                                          separately.
                                       .......................  f. Convert emissions     Method 19 F-factor
                                                                 concentration to lb/     methodology at
                                                                 TBtu or lb/GWh           appendix A-7 to part
                                                                 emission rates.          60 of this chapter, or
                                                                                          calculate using mass
                                                                                          emissions rate and
                                                                                          gross output data (see
                                                                                          Sec.   63.10007(e)).
                                       OR.....................  OR.....................
                                       Hg CEMS................  a. Install, certify,     Sections 3.2.1 and 5.1
                                                                 operate, and maintain    of appendix A of this
                                                                 the CEMS.                subpart.
                                       .......................  b. Install, certify,     Part 75 of this chapter
                                                                 operate, and maintain    and Sec.
                                                                 the diluent gas, flow    63.10010(a), (b), (c),
                                                                 rate, and/or moisture    and (d).
                                                                 monitoring systems.
                                       .......................  c. Convert hourly        Section 6 of appendix A
                                                                 emissions                to this subpart.
                                                                 concentrations to 30
                                                                 boiler operating day
                                                                 rolling average lb/
                                                                 TBtu or lb/GWh
                                                                 emissions rates.
                                       OR.....................  OR.....................
                                       Sorbent trap monitoring  a. Install, certify,     Sections 3.2.2 and 5.2
                                        system.                  operate, and maintain    of appendix A to this
                                                                 the sorbent trap         subpart.
                                                                 monitoring system.
                                       .......................  b. Install, operate,     Part 75 of this chapter
                                                                 and maintain the         and Sec.
                                                                 diluent gas, flow        63.10010(a), (b), (c),
                                                                 rate, and/or moisture    and (d).
                                                                 monitoring systems.
                                       .......................  c. Convert emissions     Section 6 of appendix A
                                                                 concentrations to 30     to this subpart.
                                                                 boiler operating day
                                                                 rolling average lb/
                                                                 TBtu or lb/GWh
                                                                 emissions rates.
                                       OR.....................  OR.....................
                                       LEE testing............  a. Select sampling       Single point located at
                                                                 ports location and the   the 10% centroidal
                                                                 number of traverse       area of the duct at a
                                                                 points.                  port location per
                                                                                          Method 1 at appendix A-
                                                                                          1 to part 60 of this
                                                                                          chapter or Method 30B
                                                                                          at Appendix A-8 for
                                                                                          Method 30B point
                                                                                          selection.
                                       .......................  b. Determine velocity    Method 2, 2A, 2C, 2F,
                                                                 and volumetric flow-     2G, or 2H at appendix
                                                                 rate of the stack gas.   A-1 or A-2 to part 60
                                                                                          of this chapter or
                                                                                          flow monitoring system
                                                                                          certified per appendix
                                                                                          A of this subpart.
                                       .......................  c. Determine oxygen and  Method 3A or 3B at
                                                                 carbon dioxide           appendix A-1 to part
                                                                 concentrations of the    60 of this chapter, or
                                                                 stack gas.               ANSI/ASME PTC 19.10-
                                                                                          1981,\3\ or diluent
                                                                                          gas monitoring systems
                                                                                          certified according to
                                                                                          part 75 of this
                                                                                          chapter.
                                       .......................  d. Measure the moisture  Method 4 at appendix A-
                                                                 content of the stack     3 to part 60 of this
                                                                 gas.                     chapter, or moisture
                                                                                          monitoring systems
                                                                                          certified according to
                                                                                          part 75 of this
                                                                                          chapter.
                                       .......................  e. Measure the Hg        Method 30B at appendix
                                                                 emission concentration.  A-8 to part 60 of this
                                                                                          chapter; perform a 30
                                                                                          operating day test,
                                                                                          with a maximum of 10
                                                                                          operating days per run
                                                                                          (i.e., per pair of
                                                                                          sorbent traps) or
                                                                                          sorbent trap
                                                                                          monitoring system or
                                                                                          Hg CEMS certified per
                                                                                          appendix A of this
                                                                                          subpart.
                                       .......................  f. Convert emissions     Method 19 F-factor
                                                                 concentrations from      methodology at
                                                                 the LEE test to lb/      appendix A-7 to part
                                                                 TBtu or lb/GWh           60 of this chapter, or
                                                                 emissions rates.         calculate using mass
                                                                                          emissions rate and
                                                                                          gross output data (see
                                                                                          Sec.   63.10007(e)).
                                       .......................  g. Convert average lb/   Potential maximum
                                                                 TBtu or lb/GWh Hg        annual heat input in
                                                                 emission rate to lb/     TBtu or potential
                                                                 year, if you are         maximum electricity
                                                                 attempting to meet the   generated in GWh.
                                                                 29.0 lb/year threshold.

[[Page 20201]]

 
5. Sulfur dioxide (SO2)..............  SO2 CEMS...............  a. Install, certify,     Part 75 of this chapter
                                                                 operate, and maintain    and Sec.   63.10010(a)
                                                                 the CEMS.                and (f).
                                       .......................  b. Install, operate,     Part 75 of this chapter
                                                                 and maintain the         and Sec.
                                                                 diluent gas, flow        63.10010(a), (b), (c),
                                                                 rate, and/or moisture    and (d).
                                                                 monitoring systems.
                                       .......................  c. Convert hourly        Method 19 F-factor
                                                                 emissions                methodology at
                                                                 concentrations to 30     appendix A-7 to part
                                                                 boiler operating day     60 of this chapter, or
                                                                 rolling average lb/      calculate using mass
                                                                 MMBtu or lb/MWh          emissions rate and
                                                                 emissions rates.         gross output data (see
                                                                                          Sec.   63.10007(e)).
----------------------------------------------------------------------------------------------------------------
\1\ Regarding emissions data collected during periods of startup or shutdown, see Sec.  Sec.   63.10020(b) and
  (c) and 63.10021(h).
\2\ See Tables 1 and 2 to this subpart for required sample volumes and/or sampling run times.
\3\ Incorporated by reference, see Sec.   63.14.


0
26. Revise Table 6 to subpart UUUUU of part 63 to read as follows:

                   Table 6 to Subpart UUUUU of Part 63--Establishing PM CPMS Operating Limits
    [As stated in Sec.   63.10007, you must comply with the following requirements for establishing operating
                                                    limits:]
----------------------------------------------------------------------------------------------------------------
                                   And you choose to
    If you have an applicable      establish PM CPMS                                           According to the
    emission limit for . . .       operating limits,       And . . .          Using . . .          following
                                    you must . . .                                             procedures . . .
----------------------------------------------------------------------------------------------------------------
Filterable Particulate matter     Install, certify,   Establish a site-   Data from the PM    1. Collect PM CPMS
 (PM), total non-mercury HAP       maintain, and       specific            CPMS and the PM     output data
 metals, individual non-mercury    operate a PM CPMS   operating limit     or HAP metals       during the entire
 HAP metals, total HAP metals,     for monitoring      in units of PM      performance tests.  period of the
 or individual HAP metals for an   emissions           CPMS output                             performance
 EGU.                              discharged to the   signal (e.g.,                           tests.
                                   atmosphere          milliamps, mg/                         2. Record the
                                   according to Sec.   acm, or other raw                       average hourly PM
                                     63.10010(h)(1).   signal).                                CPMS output for
                                                                                               each test run in
                                                                                               the performance
                                                                                               test.
                                                                                              3. Determine the
                                                                                               PM CPMS operating
                                                                                               limit in
                                                                                               accordance with
                                                                                               the requirements
                                                                                               of Sec.
                                                                                               63.10023(b)(2)
                                                                                               from data
                                                                                               obtained during
                                                                                               the performance
                                                                                               test
                                                                                               demonstrating
                                                                                               compliance with
                                                                                               the filterable PM
                                                                                               or HAP metals
                                                                                               emissions
                                                                                               limitations.
----------------------------------------------------------------------------------------------------------------


0
27. Revise Table 8 to subpart UUUUU of part 63 to read as follows:

       Table 8 to Subpart UUUUU of Part 63--Reporting Requirements
    [As stated in Sec.   63.10031, you must comply with the following
                             requirements:]
------------------------------------------------------------------------
                            The report must contain  You must submit the
    You must submit a                . . .               report . . .
------------------------------------------------------------------------
1. Compliance report.....  a. Information required   Semiannually
                            in Sec.                   according to the
                            63.10031(c)(1) through    requirements in
                            (9); and.                 Sec.
                                                      63.10031(b).
                           b. If there are no
                            deviations from any
                            emission limitation
                            (emission limit and
                            operating limit) that
                            applies to you and
                            there are no deviations
                            from the requirements
                            for work practice
                            standards in Table 3 to
                            this subpart that apply
                            to you, a statement
                            that there were no
                            deviations from the
                            emission limitations
                            and work practice
                            standards during the
                            reporting period. If
                            there were no periods
                            during which the CMSs,
                            including continuous
                            emissions monitoring
                            system, and operating
                            parameter monitoring
                            systems, were out-of-
                            control as specified in
                            Sec.   63.8(c)(7), a
                            statement that there
                            were no periods during
                            which the CMSs were out-
                            of-control during the
                            reporting period; and.
                           c. If you have a
                            deviation from any
                            emission limitation
                            (emission limit and
                            operating limit) or
                            work practice standard
                            during the reporting
                            period, the report must
                            contain the information
                            in Sec.   63.10031(d).
                            If there were periods
                            during which the CMSs,
                            including continuous
                            emissions monitoring
                            systems and continuous
                            parameter monitoring
                            systems, were out-of-
                            control, as specified
                            in Sec.   63.8(c)(7),
                            the report must contain
                            the information in Sec.
                              63.10031(e)..
------------------------------------------------------------------------


[[Page 20202]]


0
28. Revise Table 9 to subpart UUUUU of part 63 to read as follows:

Table 9 to Subpart UUUUU of Part 63--Applicability of General Provisions
                            to Subpart UUUUU
   [As stated in Sec.   63.10040, you must comply with the applicable
             General Provisions according to the following:]
------------------------------------------------------------------------
                                                     Applies to subpart
          Citation                   Subject                UUUUU
------------------------------------------------------------------------
Sec.   63.1.................  Applicability.......  Yes.
Sec.   63.2.................  Definitions.........  Yes. Additional
                                                     terms defined in
                                                     Sec.   63.10042.
Sec.   63.3.................  Units and             Yes.
                               Abbreviations.
Sec.   63.4.................  Prohibited            Yes.
                               Activities and
                               Circumvention.
Sec.   63.5.................  Preconstruction       Yes.
                               Review and
                               Notification
                               Requirements.
Sec.   63.6(a), (b)(1)        Compliance with       Yes.
 through (5), (b)(7), (c),     Standards and
 (f)(2) and (3), (h)(2)        Maintenance
 through (9), (i), (j).        Requirements.
Sec.   63.6(e)(1)(i)........  General Duty to       No. See Sec.
                               minimize emissions.   63.10000(b) for
                                                     general duty
                                                     requirement.
Sec.   63.6(e)(1)(ii).......  Requirement to        No.
                               correct
                               malfunctions ASAP.
Sec.   63.6(e)(3)...........  SSM Plan              No.
                               requirements.
Sec.   63.6(f)(1)...........  SSM exemption.......  No.
Sec.   63.6(h)(1)...........  SSM exemption.......  No.
Sec.   63.6(g)..............  Compliance with       Yes. See Sec.  Sec.
                               Standards and          63.10011(g)(4) and
                               Maintenance           63.10021(h)(4) for
                               Requirements, Use     additional
                               of an alternative     requirements.
                               non-opacity
                               emission standard.
Sec.   63.7(e)(1)...........  Performance testing.  No. See Sec.
                                                     63.10007.
Sec.   63.8.................  Monitoring            Yes.
                               Requirements.
Sec.   63.8(c)(1)(i)........  General duty to       No. See Sec.
                               minimize emissions    63.10000(b) for
                               and CMS operation.    general duty
                                                     requirement.
Sec.   63.8(c)(1)(iii)......  Requirement to        No.
                               develop SSM Plan
                               for CMS.
Sec.   63.8(d)(3)...........  Written procedures    Yes, except for last
                               for CMS.              sentence, which
                                                     refers to an SSM
                                                     plan. SSM plans are
                                                     not required.
Sec.   63.9.................  Notification          Yes, except (1) for
                               Requirements.         the 60-day
                                                     notification prior
                                                     to conducting a
                                                     performance test in
                                                     Sec.   63.9(e);
                                                     instead use a 30-
                                                     day notification
                                                     period per Sec.
                                                     63.10030(d), (2)
                                                     the notification of
                                                     the CMS performance
                                                     evaluation in Sec.
                                                      63.9(g)(1) is
                                                     limited to RATAs,
                                                     and (3) the
                                                     information
                                                     required per Sec.
                                                     63.9(h)(2)(i);
                                                     instead provide the
                                                     information
                                                     required per Sec.
                                                     63.10030(e)(1)
                                                     through (e)(6) and
                                                     (e)(8).
Sec.   63.10(a), (b)(1),      Recordkeeping and     Yes, except for the
 (c), (d)(1) and (2), (e),     Reporting             requirements to
 and (f).                      Requirements.         submit written
                                                     reports under Sec.
                                                      63.10(e)(3)(v).
Sec.   63.10(b)(2)(i).......  Recordkeeping of      No.
                               occurrence and
                               duration of
                               startups and
                               shutdowns.
Sec.   63.10(b)(2)(ii)......  Recordkeeping of      No. See Sec.
                               malfunctions.         63.10001 for
                                                     recordkeeping of
                                                     (1) occurrence and
                                                     duration and (2)
                                                     actions taken
                                                     during malfunction.
Sec.   63.10(b)(2)(iii).....  Maintenance records.  Yes.
Sec.   63.10(b)(2)(iv)......  Actions taken to      No.
                               minimize emissions
                               during SSM.
Sec.   63.10(b)(2)(v).......  Actions taken to      No.
                               minimize emissions
                               during SSM.
Sec.   63.10(b)(2)(vi)......  Recordkeeping for     Yes.
                               CMS malfunctions.
Sec.   63.10(b)(2)(vii)       Other CMS             Yes.
 through (ix).                 requirements.
Sec.   63.10(b)(3) and        ....................  No.
 (d)(3) through (5).
Sec.   63.10(c)(7)..........  Additional            Yes.
                               recordkeeping
                               requirements for
                               CMS--identifying
                               exceedances and
                               excess emissions.
Sec.   63.10(c)(8)..........  Additional            Yes.
                               recordkeeping
                               requirements for
                               CMS--identifying
                               exceedances and
                               excess emissions.
Sec.   63.10(c)(10).........  Recording nature and  No. See Sec.
                               cause of              63.10032(g) and (h)
                               malfunctions.         for malfunctions
                                                     recordkeeping
                                                     requirements.
Sec.   63.10(c)(11).........  Recording corrective  No. See Sec.
                               actions.              63.10032(g) and (h)
                                                     for malfunctions
                                                     recordkeeping
                                                     requirements.
Sec.   63.10(c)(15).........  Use of SSM Plan.....  No.
Sec.   63.10(d)(5)..........  SSM reports.........  No. See Sec.
                                                     63.10021(h) and (i)
                                                     for malfunction
                                                     reporting
                                                     requirements.
Sec.   63.11................  Control Device        No.
                               Requirements.
Sec.   63.12................  State Authority and   Yes.
                               Delegation.
Sec.  Sec.   63.13 through    Addresses,            Yes.
 63.16.                        Incorporation by
                               Reference,
                               Availability of
                               Information,
                               Performance Track
                               Provisions.

[[Page 20203]]

 
Sec.  Sec.                    Reserved............  No.
 63.1(a)(5),(a)(7) through
 (9), (b)(2), (c)(3) and
 (4), (d), 63.6(b)(6),
 (c)(3) and (4), (d),
 (e)(2), (e)(3)(ii), (h)(3),
 (h)(5)(iv), 63.8(a)(3),
 63.9(b)(3), (h)(4),
 63.10(c)(2) through (4),
 (c)(9)..
------------------------------------------------------------------------


0
29. Appendix A to subpart UUUUU of part 63 is amended by revising 
paragraphs 3.2.1.2.1, 4.1.1.1, and 4.1.1.3, table A-1, paragraphs 
4.1.1.5, 4.1.1.5.2, 5.1.2.1, and 5.1.2.3, table A-2, and paragraphs 
5.2.1, 6.2.2.3, and 7.1.8.5 and adding paragraph 7.1.2.6 to read as 
follows:

Appendix A to Subpart UUUUU of Part 63--Hg Monitoring Provisions

* * * * *

3. Mercury Emissions Measurement Methods

* * * * *
    3.2.1.2.1 NIST Traceability. Only NIST-certified or NIST-traceable 
calibration gas standards and reagents (as defined in paragraphs 3.1.4 
and 3.1.5 of this appendix), and including, but not limited to, Hg gas 
generators and Hg gas cylinders, shall be used for the tests and 
procedures required under this subpart. Calibration gases with known 
concentrations of Hg\0\ and HgCl2 are required. Special 
reagents and equipment may be needed to prepare the Hg\0\ and 
HgCl2 gas standards (e.g., NIST-traceable solutions of 
HgCl2 and gas generators equipped with mass flow 
controllers).
* * * * *

4. Certification and Recertification Requirements

* * * * *
    4.1.1.1 7-Day Calibration Error Test. Perform the 7-day calibration 
error test on 7 consecutive source operating days, using a zero-level 
gas and either a high-level or a mid-level calibration gas standard (as 
defined in paragraphs 3.1.8, 3.1.10, and 3.1.11 of this appendix). Use 
a NIST-traceable elemental Hg gas standard (as defined in paragraphs 
3.1.4 of this appendix) for the test. If your Hg CEMS lacks an 
integrated elemental Hg gas generator, you may continue to use NIST-
traceable oxidized Hg gases for the 7-day calibration error test (or 
the daily calibration error check) until such time as NIST-traceable 
compressed elemental Hg gas standards, at appropriate concentration 
levels, are available from gas vendors. If moisture is added to the 
calibration gas, the dilution effect of the moisture and/or chlorine 
addition on the calibration gas concentration must be accounted for in 
an appropriate manner. Operate the Hg CEMS in its normal sampling mode 
during the test. The calibrations should be approximately 24 hours 
apart, unless the 7-day test is performed over non-consecutive calendar 
days. On each day of the test, inject the zero-level and upscale gases 
in sequence and record the analyzer responses. Pass the calibration gas 
through all filters, scrubbers, conditioners, and other monitor 
components used during normal sampling, and through as much of the 
sampling probe as is practical. Do not make any manual adjustments to 
the monitor (i.e., resetting the calibration) until after taking 
measurements at both the zero and upscale concentration levels. If 
automatic adjustments are made following both injections, conduct the 
calibration error test such that the magnitude of the adjustments can 
be determined, and use only the unadjusted analyzer responses in the 
calculations. Calculate the calibration error (CE) on each day of the 
test, as described in Table A-1 of this appendix. The CE on each day of 
the test must either meet the main performance specification or the 
alternative specification in Table A-1 of this appendix.
* * * * *
    4.1.1.3 Three-Level System Integrity Check. Perform the 3-level 
system integrity check using low, mid, and high-level calibration gas 
concentrations generated by a NIST-traceable source of oxidized Hg. If 
your Hg CEMS lacks an integrated elemental Hg gas generator, you may 
continue to use NIST-traceable oxidized Hg gases for the 7-day 
calibration error test (or the daily calibration error check) until 
such time as NIST-traceable compressed elemental Hg gas standards, at 
appropriate concentration levels, are available from gas vendors. 
Follow the same basic procedure as for the linearity check. If moisture 
and/or chlorine is added to the calibration gas, the dilution effect of 
the moisture and/or chlorine addition on the calibration gas 
concentration must be accounted for in an appropriate manner. Calculate 
the system integrity error (SIE), as described in Table A-1 of this 
appendix. The SIE must either meet the main performance specification 
or the alternative specification in Table A-1 of this appendix.

               Table A-1--Required Certification Tests and Performance Specifications for Hg CEMS
----------------------------------------------------------------------------------------------------------------
                                                                     The alternate
 For this required certification test    The main performance         performance         And the conditions of
                . . .                   specification \1\ is .   specification \1\ is .       the alternate
                                                 . .                      . .            specification are . . .
----------------------------------------------------------------------------------------------------------------
7-day calibration error test 2 6.....  [verbar]R - A[verbar]    [verbar]R - A[verbar]    The alternate
                                        <= 5.0% of span value,   <= 1.0 [mu]g/scm.        specification may be
                                        for both the zero and                             used on any day of the
                                        upscale gases, on each                            test.
                                        of the 7 days..
Linearity check 3 6..................  [verbar]R - Aavg         [verbar]R - Aavg         The alternate
                                        [verbar] <= 10.0% of     [verbar] <= 0.8 [mu]g/   specification may be
                                        the reference gas        scm.                     used at any gas level.
                                        concentration at each
                                        calibration gas level
                                        (low, mid, or high)..
3-level system integrity check \4\...  [verbar]R - Aavg         [verbar]R - Aavg         The alternate
                                        [verbar] <= 10.0% of     [verbar] <= 0.8 [mu]g/   specification may be
                                        the reference gas        scm.                     used at any gas level.
                                        concentration at each
                                        calibration gas level..

[[Page 20204]]

 
RATA.................................  20.0% RA...............  [verbar]RMavg -          RMavg < 2.5[mu]g/scm
                                                                 Cavg[verbar] +
                                                                 [verbar]CC[verbar] <=
                                                                 0.5 [mu]g/scm \7\.
Cycle time test \5\..................  15 minutes where the
                                        stability criteria are
                                        readings change by <
                                        2.0% of span or by <=
                                        0.5 [mu]g/scm, for 2
                                        minutes..
----------------------------------------------------------------------------------------------------------------
\1\ Note that [verbar]R - A[verbar] is the absolute value of the difference between the reference gas value and
  the analyzer reading. [verbar]R - Aavg[verbar] is the absolute value of the difference between the reference
  gas concentration and the average of the analyzer responses, at a particular gas level.
\2\ Use elemental Hg standards; a mid-level or high-level upscale gas may be used.
\3\ Use elemental Hg standards.
\4\ Use oxidized Hg standards.
\5\ Use elemental Hg standards; a high-level upscale gas must be used. The cycle time test is not required for
  Hg CEMS that use integrated batch sampling; however, those monitoring systems must be capable of recording at
  least one Hg concentration reading every 15 minutes.
\6\ If your Hg CEMS lacks an integrated elemental Hg gas generator, you may continue to use NIST-traceable
  oxidized Hg gases until such time as NIST-traceable compressed elemental Hg gas standards, at appropriate
  concentration levels, are available from gas vendors.
\7\ Note that [verbar]RMavg - Cavg[verbar] is the absolute difference between the mean reference method value
  and the mean CEMS value from the RATA; CC is the confidence coefficient from Equation 2-5 of Performance
  Specification 2 in appendix B to part 60 of this chapter.

* * * * *
    4.1.1.5 Relative Accuracy Test Audit (RATA). Perform the RATA of 
the Hg CEMS at normal load. Acceptable Hg reference methods for the 
RATA include ASTM D6784-02 (Reapproved 2008), ``Standard Test Method 
for Elemental, Oxidized, Particle-Bound and Total Mercury in Flue Gas 
Generated from Coal-Fired Stationary Sources (Ontario Hydro Method)'' 
(incorporated by reference, see Sec.  63.14) and Methods 29, 30A, and 
30B in appendix A-8 to part 60 of this chapter. When Method 29 or ASTM 
D6784-02 is used, paired sampling trains are required and the 
filterable portion of the sample need not be included when making 
comparisons to the Hg CEMS results for purposes of a RATA. To validate 
a Method 29 or ASTM D6784-02 test run, calculate the relative deviation 
(RD) using Equation A-1 of this section, and assess the results as 
follows to validate the run. The RD must not exceed 10 percent, when 
the average Hg concentration is greater than 1.0 [mu]g/dscm. If the RD 
specification is met, the results of the two samples shall be averaged 
arithmetically.
[GRAPHIC] [TIFF OMITTED] TR06AP16.008

Where:

RD = Relative Deviation between the Hg concentrations of samples 
``a'' and ``b'' (percent),
Ca = Hg concentration of Hg sample ``a'' ([mu] g/dscm), 
and
Cb = Hg concentration of Hg sample ``b'' ([mu] g/dscm).
* * * * *
    4.1.1.5.2 Calculation of RATA Results. Calculate the relative 
accuracy (RA) of the monitoring system, on a [mu] g/scm basis, as 
described in section 12 of Performance Specification (PS) 2 in appendix 
B to part 60 of this chapter (see Equations 2-3 through 2-6 of PS2) 
including the option to substitute the emission limit value (in this 
case the equivalent concentration) in the denominator of Equation 2-6 
in place of the average RM value when the average emissions for the 
test are less than 50 percent of the applicable emissions limit. For 
purposes of calculating the relative accuracy, ensure that the 
reference method and monitoring system data are on a consistent basis, 
either wet or dry. The CEMS must either meet the main performance 
specification or the alternative specification in Table A-1 of this 
appendix.
* * * * *

5. Ongoing Quality Assurance (QA) and Data Validation

* * * * *
    5.1.2.1 Calibration error tests of the Hg CEMS are required daily, 
except during unit outages. Use a NIST-traceable elemental Hg gas 
standard for these calibrations. If your Hg CEMS lacks an integrated 
elemental Hg gas generator, you may continue to use NIST-traceable 
oxidized Hg gases for the 7-day calibration error test (or the daily 
calibration error check) until such time as NIST-traceable compressed 
elemental Hg gas standards, at appropriate concentration levels, are 
available from gas vendors. Both a zero-level gas and either a mid-
level or high-level gas are required for these calibrations.
* * * * *
    5.1.2.3 Perform a single-level system integrity check weekly, i.e., 
once every 7 operating days (see the third column in Table A-2 of this 
appendix).
* * * * *

[[Page 20205]]



                              Table A-2--On-Going QA Test Requirements for Hg CEMS
----------------------------------------------------------------------------------------------------------------
                                                                       With these
  Perform this type of QA test . . .   At this frequency . . .     qualifications and    Acceptance criteria . .
                                                                    exceptions . . .                .
----------------------------------------------------------------------------------------------------------------
Calibration error test \5\...........  Daily..................   Use either a    [verbar]R - A[verbar]
                                                                 mid- or high-level gas.  <= 5.0% of span value
                                                                 Use elemental   or
                                                                 Hg.                     [verbar]R - A[verbar]
                                                                 Calibrations     <= 1.0 [mu]g/scm.
                                                                 are not required when
                                                                 the unit is not in
                                                                 operation..
Single-level system integrity check..  Weekly \1\.............   Use oxidized    [verbar]R -
                                                                 Hg--either mid- or       Aavg[verbar] <= 10.0%
                                                                 high-level.              of the reference gas
                                                                                          value
                                                                                         or
                                                                                         [verbar]R -
                                                                                          Aavg[verbar] <= 0.8
                                                                                          [mu]g/scm.
Linearity check or 3-level system      Quarterly \3\..........   Required in     [verbar]R - Aavg
 integrity check.                                                each ``QA operating      [verbar] <= 10.0% of
                                                                 quarter'' \2\ and no     the reference gas
                                                                 less than once every 4   value, at each
                                                                 calendar quarters.       calibration gas level
                                                                 168 operating   or
                                                                 hour grace period       [verbar]R -
                                                                 available.               Aavg[verbar] <= 0.8
                                                                 Use elemental    [mu]g/scm.
                                                                 Hg for linearity check.
                                                                 Use oxidized
                                                                 Hg for system
                                                                 integrity check.
RATA.................................  Annual \4\.............   Test deadline   <=20.0% RA when Cavg >=
                                                                 may be extended for      2.5 [mu]g/scm
                                                                 ``non-QA operating      or
                                                                 quarters,'' up to a     [verbar]RMavg -
                                                                 maximum of 8 quarters    Cavg[verbar] +
                                                                 from the quarter of      [verbar]CC[verbar] <=
                                                                 the previous test..      0.5 [mu]g[mu]/scm, if
                                                                 720 operating    RMavg < 2.5 [mu]g/scm.
                                                                 hour grace period
                                                                 available.
----------------------------------------------------------------------------------------------------------------
\1\ ``Weekly'' means once every 7 operating days.
\2\ A ``QA operating quarter'' is a calendar quarter with at least 168 unit or stack operating hours.
\3\ ``Quarterly'' means once every QA operating quarter.
\4\ ``Annual'' means once every four QA operating quarters.
\5\ If your Hg CEMS lacks an integrated elemental Hg gas generator, you may continue to use NIST-traceable
  oxidized Hg gases until such time as NIST-traceable compressed elemental Hg gas standards, at appropriate
  concentration levels, are available from gas vendors.

* * * * *
    5.2.1 Each sorbent trap monitoring system shall be continuously 
operated and maintained in accordance with Performance Specification 
(PS) 12B in appendix B to part 60 of this chapter. The QA/QC criteria 
for routine operation of the system are summarized in Table 12B-1 of PS 
12B. Each pair of sorbent traps may be used to sample the stack gas for 
up to 15 operating days.
* * * * *

6. Data Reductions and Calculations

* * * * *
    6.2.2.3 The applicable gross output-based Hg emission rate limit in 
Table 1 or 2 to this subpart must be met on a 30- (or 90-) boiler 
operating day rolling average basis, except as otherwise provided in 
Sec.  63.10009(a)(2). Use Equation A-5 of this appendix to calculate 
the Hg emission rate for each averaging period.
[GRAPHIC] [TIFF OMITTED] TR06AP16.009

Where:

Eo = Hg emission rate for the averaging period (lb/GWh),
Eho = Gross output-based hourly Hg emission rate for unit 
or stack sampling hour ``h'' in the averaging period, from Equation 
A-4 of this appendix (lb/GWh), and
n = Number of unit or stack operating hours in the averaging period 
in which valid data were obtained for all parameters. (Note: Do not 
include non-operating hours with zero emission rates in the 
average).
* * * * *

7. Recordkeeping and Reporting

* * * * *
    7.1.2.6 The EGUs that constitute an emissions averaging group.
* * * * *
    7.1.8.5 If applicable, a code to indicate that the default gross 
output (as defined in Sec.  63.10042) was used to calculate the Hg 
emission rate.
* * * * *

0
30. Appendix B to subpart UUUUU of part 63 is amended by:
0
a. Revising paragraphs 2.1 and 2.3;
0
b. Adding paragraphs 2.3.1 and 2.3.2;
0
c. Revising paragraphs 3.1 and 3.2 and adding paragraph 3.3;
0
d. Adding introductory text to section 5;
0
e. Revising paragraphs 5.1, 5.1.2, 5.2, and 5.3;
0
f. Adding paragraphs 5.4, 5.4.1, 5.4.2, 5.4.2.1, 5.4.2.2, 5.4.2.2.1, 
5.4.2.2.2, 5.4.2.3, 5.4.2.3.1, 5.4.2.3.2, 5.4.2.3.3, and 5.4.3; and
0
g. Revising section 8 introductory text and paragraph 9.3.2.
    The revisions and additions read as follows:

Appendix B to Subpart UUUUU of Part 63--HCl and HF Monitoring 
Provisions

* * * * *

2. Monitoring of HCl and/or HF Emissions

    2.1 Monitoring System Installation Requirements. Install HCl and/or 
HF CEMS and any additional monitoring systems needed to convert 
pollutant concentrations to units of the applicable emissions limit in 
accordance with Sec.  63.10010(a) and either Performance Specification 
15 (PS 15) of appendix B to part 60 of this chapter for extractive 
Fourier Transform Infrared Spectroscopy (FTIR) continuous emissions 
monitoring systems or Performance Specification 18 (PS 18) of appendix 
B to part 60 of this chapter for HCl CEMS.
* * * * *

[[Page 20206]]

    2.3 FTIR Monitoring System Equipment, Supplies, Definitions, and 
General Operation. The following provisions apply:
    2.3.1 PS 15, Sections 2.0, 3.0, 4.0, 5.0, 6.0, and 10.0 of appendix 
B to part 60 of this chapter; or
    2.3.2 PS 18, Sections 3.0, 6.0, and 11.0 of appendix B to part 60 
of this chapter.

3. Initial Certification Procedures

* * * * *
    3.1 If you choose to follow PS 15 of appendix B to part 60 of this 
chapter, then your HCl and/or HF CEMS must be certified according to PS 
15 using the procedures for gas auditing and comparison to a reference 
method (RM) as specified in sections 3.1.1 and 3.1.2 below.
* * * * *
    3.2 If you choose to follow PS 18 of appendix B to part 60 of this 
chapter, then your HCl CEMS must be certified according to PS 18, 
sections 7.0, 8.0, 11.0, 12.0, and 13.0.
    3.3 Any additional stack gas flow rate, diluent gas, and moisture 
monitoring system(s) needed to express pollutant concentrations in 
units of the applicable emissions limit must be certified according to 
part 75 of this chapter.
* * * * *

5. On-Going Quality Assurance Requirements

    On-going QA test requirements for HCl and HF CEMS must be 
implemented as follows:
    5.1 If you choose to follow Performance Specification 15 (PS 15) of 
appendix B to part 60 of this chapter, then the quality assurance/
quality control procedures of PS 15 shall apply as set forth in 
sections 5.1.1 through 5.1.3 and 5.4.2 of this appendix.
* * * * *
    5.1.2 On a quarterly basis, you must conduct a gas audit of the HCl 
and/or HF CEMS as described in section 3.1.1 of this appendix. For the 
purposes of this appendix, ``quarterly'' means once every ``QA 
operating quarter'' (as defined in section 3.1.20 of appendix A to this 
subpart). You have the option to use HCl gas in lieu of HF gas for 
conducting this audit on an HF CEMS. To the extent practicable, perform 
consecutive quarterly gas audits at least 30 days apart. The initial 
quarterly audit is due in the first QA operating quarter following the 
calendar quarter in which certification testing of the CEMS is 
successfully completed. Up to three consecutive exemptions from the 
quarterly audit requirement are allowed for ``non-QA operating 
quarters'' (i.e., calendar quarters in which there are less than 168 
unit or stack operating hours). However, no more than four consecutive 
calendar quarters may elapse without performing a gas audit, except as 
otherwise provided in section 5.4.2.2.1 of this appendix.
* * * * *
    5.2 If you choose to follow Performance Specification PS 18 of 
appendix B to part 60 of this chapter, then the quality assurance/
quality control procedures in Procedure 6 of appendix F to part 60 of 
this chapter shall apply. The quarterly and annual QA tests required 
under Procedure 6 shall be performed, respectively, at the frequencies 
specified in sections 5.1.2 and 5.1.3 of this appendix.
    5.3 Stack gas flow rate, diluent gas, and moisture monitoring 
systems must meet the applicable on-going QA test requirements of part 
75 of this chapter.
* * * * *
    5.4 Data Validation.
    5.4.1 Out-of-Control Periods. An HCl or HF CEMS that is used to 
provide data under this appendix is considered to be out-of-control, 
and data from the CEMS may not be reported as quality-assured, when any 
acceptance criteria for a required QA test is not met. The HCl or HF 
CEMS is also considered to be out-of-control when a required QA test is 
not performed on schedule or within an allotted grace period. To end an 
out-of-control period, the QA test that was either failed or not done 
on time must be performed and passed. Out-of-control periods are 
counted as hours of monitoring system downtime.
    5.4.2 Grace Periods. For the purposes of this appendix, a ``grace 
period'' is defined as a specified number of unit or stack operating 
hours after the deadline for a required quality-assurance test of a 
continuous monitor has passed, in which the test may be performed and 
passed without loss of data.
    5.4.2.1 For the monitoring systems described in section 5.3 of this 
appendix, a 168 unit or stack operating hour grace period is available 
for quarterly linearity checks, and a 720 unit or stack operating hour 
grace period is available for RATAs, as provided, respectively, in 
sections 2.2.4 and 2.3.3 of appendix B to part 75 of this chapter.
    5.4.2.2 For the purposes of this appendix, if the deadline for a 
required gas audit/data accuracy assessment or RATA of an HCl CEMS 
cannot be met due to circumstances beyond the control of the owner or 
operator:
    5.4.2.2.1 A 168 unit or stack operating hour grace period is 
available in which to perform the gas audit or other quarterly data 
accuracy assessment; or
    5.4.2.2.2 A 720 unit or stack operating hour grace period is 
available in which to perform the RATA.
    5.4.2.3 If a required QA test is performed during a grace period, 
the deadline for the next test shall be determined as follows:
    5.4.2.3.1 For a gas audit or RATA of the monitoring systems 
described in sections 5.1 and 5.2 of this appendix, determine the 
deadline for the next gas audit or RATA (as applicable) in accordance 
with section 2.2.4(b) or 2.3.3(d) of appendix B to part 75 of this 
chapter; treat a gas audit in the same manner as a linearity check.
    5.4.2.3.2 For the gas audit or other quarterly data accuracy 
assessment of an HCl or HF CEMS, the grace period test only satisfies 
the audit requirement for the calendar quarter in which the test was 
originally due. If the calendar quarter in which the grace period audit 
is performed is a QA operating quarter, an additional gas audit/data 
accuracy assessment is required for that quarter.
    5.4.2.3.3 For the RATA of an HCl or HF CEMS, the next RATA is due 
within three QA operating quarters after the calendar quarter in which 
the grace period test is performed.
    5.4.3 Conditional Data Validation. For recertification and 
diagnostic testing of the monitoring systems that are used to provide 
data under this appendix, the conditional data validation provisions in 
Sec.  75.20(b)(3)(ii) through (ix) of this chapter may be used to avoid 
or minimize data loss. The allotted window of time to complete 
calibration tests and RATAs shall be as specified in Sec.  
75.20(b)(3)(iv) of this chapter; the allotted window of time to 
complete a quarterly gas audit or data accuracy assessment shall be the 
same as for a linearity check (i.e., 168 unit or stack operating 
hours).
* * * * *

8. QA/QC Program Requirements

    The owner or operator shall develop and implement a quality 
assurance/quality control (QA/QC) program for the HCl and/or HF CEMS 
that are used to provide data under this subpart. At a minimum, the 
program shall include a written plan that describes in detail (or that 
refers to separate documents containing) complete, step-by-step 
procedures and operations for the most important QA/QC activities. 
Electronic storage of the QA/QC plan is permissible, provided that the 
information can be made available in hard copy to auditors and 
inspectors. The QA/QC program requirements for

[[Page 20207]]

the other monitoring systems described in section 5.3 of this appendix 
are specified in section 1 of appendix B to part 75 of this chapter.
* * * * *

9. Data Reduction and Calculations

* * * * *
    9.3.2 For gross output-based emission rates, first calculate the 
HCl or HF mass emission rate (lb/h), using an equation that has the 
general form of Equation A-2 or A-3 in appendix A to this subpart (as 
applicable), replacing the value of K with 9.43 x 10-8 lb/
scf-ppm (for HCl) or 5.18 x 10-8 (for HF) and defining 
Ch as the hourly average HCl or HF concentration in ppm. 
Then, divide the result by the hourly gross output (megawatts) to 
convert it to units of lb/MWh. If the gross output is zero during a 
startup or shutdown hour, use the default gross output (as defined in 
Sec.  63.10042) to calculate the HCl or HF emission rate. The default 
gross output is not considered to be a substitute data value.
* * * * *
[FR Doc. 2016-06563 Filed 4-5-16; 8:45 am]
 BILLING CODE 6560-50-P